10-Q

United States

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

[X] Quarterly Report Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the quarterly period ended:

September 30, 2014

[ ] Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934

For the transition period from _______________ to _______________

Commission File No.	Name of Registrant, State of Incorporation, Address of Principal Executive Offices, and Telephone No.	IRS Employer Identification No.
000-49965	MGE Energy, Inc. (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 mgeenergy.com	39-2040501
000-1125	Madison Gas and Electric Company (a Wisconsin Corporation) 133 South Blair Street Madison, Wisconsin 53788 (608) 252-7000 mge.com	39-0444025

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) have been subject to such filing requirements for the past 90 days: Yes [X] No [ ]

Indicate by check mark whether the registrants have submitted electronically and posted on their corporate Web sites, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrants were required to submit and post such files):

Yes [X] No [ ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of "large accelerated filer," "accelerated filer," and "smaller reporting company" in Rule 12b-2 of the Exchange Act.

	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer	Smaller Reporting Company
MGE Energy, Inc.	X
Madison Gas and Electric Company			X

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):

MGE Energy, Inc. and Madison Gas and Electric Company: Yes [ ] No [X]

Number of Shares Outstanding of Each Class of Common Stock as of October 31, 2014
MGE Energy, Inc.	Common stock, $1.00 par value, 34,668,370 shares outstanding.
Madison Gas and Electric Company	Common stock, $1.00 par value, 17,347,894 shares outstanding (all of which are owned beneficially and of record by MGE Energy, Inc.).

1

Table of Contents

2

PART I. FINANCIAL INFORMATION.

Filing Format

This combined Form 10-Q is being filed separately by MGE Energy, Inc. (MGE Energy) and Madison Gas and Electric Company (MGE). MGE is a wholly owned subsidiary of MGE Energy and represents a majority of its assets, liabilities, revenues, expenses, and operations. Thus, all information contained in this report relates to, and is filed by, MGE Energy. Information that is specifically identified in this report as relating solely to MGE Energy, such as its financial statements and information relating to its nonregulated business, does not relate to, and is not filed by, MGE. MGE makes no representation as to that information. The terms "we" and "our," as used in this report, refer to MGE Energy and its consolidated subsidiaries, unless otherwise indicated.

Forward-Looking Statements

This report, and other documents filed by MGE Energy and MGE with the Securities and Exchange Commission (SEC) from time to time, contain forward-looking statements that reflect management's current assumptions and estimates regarding future performance and economic conditions—especially as they relate to economic conditions, future load growth, revenues, expenses, capital expenditures, financial resources, regulatory matters, and the scope and expense associated with future environmental regulation. These forward-looking statements are made pursuant to the provisions of the Private Securities Litigation Reform Act of 1995. Words such as "believe," "expect," "anticipate," "estimate," "could," "should," "intend," "will," and other similar words generally identify forward-looking statements. Both MGE Energy and MGE caution investors that these forward-looking statements are subject to known and unknown risks and uncertainties that may cause actual results to differ materially from those projected, expressed, or implied.

The factors that could cause actual results to differ materially from the forward-looking statements made by a registrant include (a) those factors discussed in the Registrants' 2013 Annual Report on Form 10-K: Item 1A. Risk Factors, as updated by Part II. Item 1A. Risk Factors in this Report, Item 7. Management's Discussion and Analysis of Financial Condition and Results of Operations, as updated by Part I, Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations in this report, and Item 8. Financial Statements and Supplementary Data – Note 18, as updated by Part I, Item 1. Financial Statements – Note 8 in this report, and (b) other factors discussed herein and in other filings made by that registrant with the SEC.

Readers are cautioned not to place undue reliance on these forward-looking statements, which apply only as of the date of this report. MGE Energy and MGE undertake no obligation to release publicly any revision to these forward-looking statements to reflect events or circumstances after the date of this report.

Stock Split

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's outstanding shares of common stock, effective in the form of a stock dividend. Shareholders of record at the close of business on January 24, 2014, received one additional share of MGE Energy common stock for every two shares of common stock owned on that date. The additional shares were distributed on February 7, 2014. All share and per share data provided in this report give effect to this stock split.

Where to Find More Information

The public may read and copy any reports or other information that MGE Energy and MGE file with the SEC at the SEC's public reference room at 100 F Street, NE, Washington, D.C. 20549. The public may obtain information on the operation of the Public Reference Room by calling the SEC at 1-800-SEC-0330. These documents also are available to the public from commercial document retrieval services, the website maintained by the SEC at sec.gov, MGE Energy's website at mgeenergy.com, and MGE's website at mge.com. Copies may be obtained from our websites free of charge. Information contained on MGE Energy's and MGE's websites shall not be deemed incorporated into, or to be a part of, this report.

3

Definitions, Abbreviations, and Acronyms Used in the Text and Notes of this Report

Abbreviations, acronyms, and definitions used in the text and notes of this report are defined below.

MGE Energy and Subsidiaries:
CWDC	Central Wisconsin Development Corporation
MAGAEL	MAGAEL, LLC
MGE	Madison Gas and Electric Company
MGE Energy	MGE Energy, Inc.
MGE Power	MGE Power, LLC
MGE Power Elm Road	MGE Power Elm Road, LLC
MGE Power West Campus	MGE Power West Campus, LLC
MGE State Energy Services	MGE State Energy Services, LLC
MGE Transco	MGE Transco Investment, LLC
NGV Fueling Services	NGV Fueling Services, LLC
North Mendota	North Mendota Energy & Technology Park, LLC
Other Defined Terms:
AFUDC	Allowance for Funds Used During Construction
ATC	American Transmission Company LLC
Blount	Blount Station
CA	Certificate of Authority
CAA	Clean Air Act
CAIR	Clean Air Interstate Rule
CAVR	Clean Air Visibility Rule
CCC	Closed Cycle Cooling
CCR	Coal Combustion Residual
Codification	Financial Accounting Standards Board Accounting Standards Codification
Columbia	Columbia Energy Center
Cooling degree days	Measure of the extent to which the average daily temperature is above 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide cooling
CSAPR	Cross-State Air Pollution Rule
Dth	Dekatherms, a quantity measure used in respect of natural gas
EGUs	Electric Generating Units
Elm Road Units	Elm Road Generating Station
EPA	United States Environmental Protection Agency
FASB	Financial Accounting Standards Board
FTR	Financial Transmission Rights
GHG	Greenhouse Gas
Heating degree days (HDD)	Measure of the extent to which the average daily temperature is below 65 degrees Fahrenheit, which is considered an indicator of possible increased demand for energy to provide heating
IRS	Internal Revenue Service
kWh	Kilowatt-hour, a measure of electric energy produced
MATS	Mercury and Air Toxics Standards
MISO	Midcontinent Independent System Operator (a regional transmission organization)
MW	Megawatt, a measure of electric energy generating capacity
MWh	Megawatt-hour, a measure of electric energy produced
NAAQS	National Ambient Air Quality Standards
NOL	Net Operating Loss
NOV	Notice of Violation
NOx	Nitrogen Oxides
NSPS	New Source Performance Standards

4

PGA	Purchased Gas Adjustment clause, a regulatory mechanism used to reconcile natural gas costs recovered in rates to actual costs
PJM	PJM Interconnection, LLC (a regional transmission organization)
PPA	Purchased Power Agreement
PSCW	Public Service Commission of Wisconsin
PSD	Prevention of Significant Deterioration
ROE	Return on Equity
SCR	Selective Catalytic Reduction
SEC	Securities and Exchange Commission
SIP	State Implementation Plan
SO2	Sulfur Dioxide
the State	State of Wisconsin
Stock Plan	Direct Stock Purchase and Dividend Reinvestment Plan of MGE Energy
UW	University of Wisconsin at Madison
VIE	Variable Interest Entity
WCCF	West Campus Cogeneration Facility
WDNR	Wisconsin Department of Natural Resources
WEPCO	Wisconsin Electric Power Company
Working capital	Current assets less current liabilities
WPL	Wisconsin Power and Light Company
WPSC	Wisconsin Public Service Corporation
XBRL	eXtensible Business Reporting Language

5

Item 1. Financial Statements.

MGE Energy, Inc.

Consolidated Statements of Income (unaudited)

(In thousands, except per-share amounts)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
Operating Revenues:
Regulated electric revenues	$	112,869	$	119,836	$	308,418	$	310,176
Regulated gas revenues		21,404		18,864		163,335		121,373
Nonregulated revenues		862		1,399		2,392		4,075
Total Operating Revenues		135,135		140,099		474,145		435,624
Operating Expenses:
Fuel for electric generation		9,838		13,950		35,836		34,520
Purchased power		21,303		21,981		58,779		61,237
Cost of gas sold		11,039		8,819		107,679		70,259
Other operations and maintenance		37,587		41,134		118,267		124,670
Depreciation and amortization		10,376		9,710		30,191		28,864
Other general taxes		4,872		4,605		14,861		14,049
Total Operating Expenses		95,015		100,199		365,613		333,599
Operating Income		40,120		39,900		108,532		102,025
Other income, net		2,636		3,750		10,736		9,770
Interest expense, net		(5,141)		(4,605)		(14,550)		(13,937)
Income before income taxes		37,615		39,045		104,718		97,858
Income tax provision		(14,286)		(14,692)		(39,585)		(37,030)
Net Income	$	23,329	$	24,353	$	65,133	$	60,828
Earnings Per Share of Common Stock
(basic and diluted)	$	0.67	$	0.70	$	1.88	$	1.75
Dividends per share of common stock	$	0.283	$	0.272	$	0.826	$	0.799
Weighted Average Shares Outstanding
(basic and diluted)		34,668		34,668		34,668		34,668
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

MGE Energy, Inc.

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
Net Income	$	23,329	$	24,353	$	65,133	$	60,828
Other comprehensive income, net of tax:
Unrealized gain on available-for-sale
securities, net of tax ($63 and $24, and $38 and
$117, respectively)		95		36		56		176
Comprehensive Income	$	23,424	$	24,389	$	65,189	$	61,004
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

6

MGE Energy, Inc.

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Nine Months Ended
		September 30,
		2014		2013
Operating Activities:
Net income	$	65,133	$	60,828
Items not affecting cash:
Depreciation and amortization		30,191		28,864
Deferred income taxes		24,376		32,706
Provision for doubtful receivables		1,001		1,551
Employee benefit plan expenses		(814)		9,908
Equity earnings in ATC		(7,306)		(7,045)
Other items		(843)		250
Changes in working capital items:
Decrease in current assets		13,318		15,053
Decrease in current liabilities		(7,515)		(5,496)
Dividend income from ATC		5,762		5,498
Cash contributions to pension and other postretirement plans		(2,449)		(33,919)
Debt make-whole premium		-		(6,757)
Other noncurrent items, net		118		7,159
Cash Provided by Operating Activities		120,972		108,600
Investing Activities:
Capital expenditures		(66,138)		(92,092)
Capital contributions to investments		(1,830)		(1,305)
Other		(1,265)		(780)
Cash Used for Investing Activities		(69,233)		(94,177)
Financing Activities:
Cash dividends paid on common stock		(28,634)		(27,685)
Repayment of long-term debt		(3,069)		(42,000)
Issuance of long-term debt		-		85,000
Other		(130)		(765)
Cash (Used for) Provided by Financing Activities		(31,833)		14,550
Change in cash and cash equivalents		19,906		28,973
Cash and cash equivalents at beginning of period		68,813		46,357
Cash and Cash Equivalents at End of Period	$	88,719	$	75,330
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	6,549	$	10,473
The accompanying notes are an integral part of the unaudited consolidated financial statements.

7

MGE Energy, Inc.

Consolidated Balance Sheets (unaudited)

(In thousands)

		September 30,	December 31,
ASSETS		2014		2013
Current Assets:
Cash and cash equivalents	$	88,719	$	68,813
Accounts receivable, less reserves of $4,056 and $4,219, respectively		35,251		44,890
Other accounts receivable, less reserves of $448 and $750, respectively		5,365		5,352
Unbilled revenues		19,929		31,982
Materials and supplies, at average cost		17,524		16,662
Fossil fuel		5,121		5,206
Stored natural gas, at average cost		23,292		13,988
Prepaid taxes		15,569		19,106
Regulatory assets - current		4,985		6,377
Other current assets		9,650		8,225
Total Current Assets		225,405		220,601
Regulatory assets		100,227		107,166
Pension benefits		17,942		15,071
Other deferred assets and other		7,029		8,046
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,176,592		1,018,809
Construction work in progress		21,331		141,415
Total Property, Plant, and Equipment		1,197,923		1,160,224
Investments		71,370		67,952
Total Assets	$	1,619,896	$	1,579,060
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,162	$	4,102
Accounts payable		41,871		43,684
Accrued interest and taxes		4,041		5,661
Accrued payroll related items		10,305		10,731
Deferred income taxes		-		1,711
Regulatory liabilities - current		8,822		13,538
Derivative liabilities		7,131		7,750
Other current liabilities		5,824		9,489
Total Current Liabilities		82,156		96,666
Other Credits:
Deferred income taxes		313,101		284,791
Investment tax credit - deferred		1,274		1,413
Regulatory liabilities		21,970		19,792
Accrued pension and other postretirement benefits		50,339		49,184
Derivative liabilities		47,820		57,930
Other deferred liabilities and other		52,947		52,360
Total Other Credits		487,451		465,470
Capitalization:
Common shareholders' equity		653,985		617,510
Long-term debt		396,304		399,414
Total Capitalization		1,050,289		1,016,924
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,619,896	$	1,579,060
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

8

MGE Energy, Inc.

Consolidated Statements of Common Equity (unaudited)

(In thousands, except per-share amounts)

									Accumulated
					Additional				Other
	Common Stock				Paid-in		Retained		Comprehensive
	Shares		Value		Capital		Earnings		Income		Total
2013
Beginning balance - December 31, 2012	34,668	$	34,668	$	316,268	$	228,399	$	94	$	579,429
Net income							60,828				60,828
Other comprehensive income									176		176
Common stock dividends declared
($ 0.799 per share)							(27,685)				(27,685)
Ending balance - September 30, 2013	34,668	$	34,668	$	316,268	$	261,542	$	270	$	612,748
2014
Beginning balance - December 31, 2013	34,668	$	34,668	$	316,268	$	266,197	$	377	$	617,510
Net income							65,133				65,133
Other comprehensive income									56		56
Common stock dividends declared
($0.826 per share)							(28,634)				(28,634)
Cash in lieu of fractional shares related
to stock split							(80)				(80)
Ending balance - September 30, 2014	34,668	$	34,668	$	316,268	$	302,616	$	433	$	653,985
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

9

Madison Gas and Electric Company

Consolidated Statements of Income (unaudited)

(In thousands)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
Operating Revenues:
Regulated electric revenues	$	112,875	$	119,836	$	308,435	$	310,176
Regulated gas revenues		21,410		18,864		163,351		121,373
Nonregulated revenues		862		1,399		2,392		4,075
Total Operating Revenues		135,147		140,099		474,178		435,624
Operating Expenses:
Fuel for electric generation		9,841		13,950		35,843		34,520
Purchased power		21,307		21,981		58,790		61,237
Cost of gas sold		11,045		8,819		107,695		70,259
Other operations and maintenance		37,309		40,990		117,593		124,133
Depreciation and amortization		10,364		9,710		30,156		28,864
Other general taxes		4,872		4,605		14,861		14,049
Income tax provision		13,338		13,798		36,180		34,237
Total Operating Expenses		108,076		113,853		401,118		367,299
Operating Income		27,071		26,246		73,060		68,325
Other Income and Deductions:
AFUDC - equity funds		255		852		3,306		2,178
Equity in earnings in ATC		2,423		2,340		7,306		7,045
Income tax provision		(984)		(880)		(3,390)		(2,802)
Other income, net		(111)		407		(351)		118
Total Other Income and Deductions		1,583		2,719		6,871		6,539
Income before interest expense		28,654		28,965		79,931		74,864
Interest Expense:
Interest on long-term debt		5,225		4,910		15,714		14,757
Other interest, net		44		5		52		(31)
AFUDC - borrowed funds		(84)		(281)		(1,090)		(718)
Net Interest Expense		5,185		4,634		14,676		14,008
Net Income	$	23,469	$	24,331	$	65,255	$	60,856
Less: Net Income Attributable to Noncontrolling
Interest, net of tax		(6,653)		(6,861)		(19,784)		(20,547)
Net Income Attributable to MGE	$	16,816	$	17,470	$	45,471	$	40,309
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

Madison Gas and Electric Company

Consolidated Statements of Comprehensive Income (unaudited)

(In thousands)

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
		2014		2013		2014		2013
Net Income	$	23,469	$	24,331	$	65,255	$	60,856
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale
securities, net of tax (($29) and ($33), and $36 and
($52), respectively)		43		49		(54)		77
Comprehensive Income	$	23,512	$	24,380	$	65,201	$	60,933
Less: Comprehensive Income Attributable to
Noncontrolling Interest, net of tax		(6,653)		(6,861)		(19,784)		(20,547)
Comprehensive Income Attributable to MGE	$	16,859	$	17,519	$	45,417	$	40,386
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

10

Madison Gas and Electric Company

Consolidated Statements of Cash Flows (unaudited)

(In thousands)

		Nine Months Ended
		September 30,
		2014		2013
Operating Activities:
Net income	$	65,255	$	60,856
Items not affecting cash:
Depreciation and amortization		30,156		28,864
Deferred income taxes		23,811		31,467
Provision for doubtful receivables		1,001		1,551
Employee benefit plan expenses		(814)		9,908
Equity earnings in ATC		(7,306)		(7,045)
Other items		(446)		652
Changes in working capital items:
Decrease in current assets		13,258		14,599
Decrease in current liabilities		(5,457)		(4,911)
Dividend income from ATC		5,762		5,498
Cash contributions to pension and other postretirement plans		(2,449)		(33,919)
Debt make-whole premium		-		(6,757)
Other noncurrent items, net		(24)		7,063
Cash Provided by Operating Activities		122,747		107,826
Investing Activities:
Capital expenditures		(66,138)		(92,092)
Capital contributions to investments		(1,420)		(1,065)
Other		(1,087)		(678)
Cash Used for Investing Activities		(68,645)		(93,835)
Financing Activities:
Cash dividends paid to parent by MGE		(26,500)		-
Distributions to parent from noncontrolling interest		(17,778)		(21,148)
Equity contribution received by noncontrolling interest		1,420		1,065
Repayment of long-term debt		(3,069)		(42,000)
Issuance of long-term debt		-		85,000
Other		-		(668)
Cash (Used for) Provided by Financing Activities		(45,927)		22,249
Change in cash and cash equivalents		8,175		36,240
Cash and cash equivalents at beginning of period		14,808		6,350
Cash and Cash Equivalents at End of Period	$	22,983	$	42,590
Supplemental disclosures of cash flow information:
Significant noncash investing activities:
Accrued capital expenditures	$	6,549	$	10,473
The accompanying notes are an integral part of the unaudited consolidated financial statements.

11

Madison Gas and Electric Company

Consolidated Balance Sheets (unaudited)

(In thousands)

		September 30,	December 31,
ASSETS		2014		2013
Current Assets:
Cash and cash equivalents	$	22,983	$	14,808
Accounts receivable, less reserves of $4,056 and $4,219, respectively		35,251		44,890
Affiliate receivables		609		534
Other accounts receivable, less reserves of $448 and $750, respectively		5,290		5,274
Unbilled revenues		19,929		31,982
Materials and supplies, at average cost		17,524		16,662
Fossil fuel		5,121		5,206
Stored natural gas, at average cost		23,292		13,988
Prepaid taxes		20,390		23,934
Regulatory assets - current		4,985		6,377
Other current assets		9,546		8,197
Total Current Assets		164,920		171,852
Affiliate receivable long-term		5,428		5,825
Regulatory assets		100,227		107,166
Pension benefits		17,942		15,071
Other deferred assets and other		4,987		6,138
Property, Plant, and Equipment:
Property, plant, and equipment, net		1,175,695		1,017,877
Construction work in progress		21,331		141,415
Total Property, Plant, and Equipment		1,197,026		1,159,292
Investments		68,172		65,299
Total Assets	$	1,558,702	$	1,530,643
LIABILITIES AND CAPITALIZATION
Current Liabilities:
Long-term debt due within one year	$	4,162	$	4,102
Accounts payable		41,861		43,684
Accrued interest and taxes		3,774		6,040
Accrued payroll related items		10,305		10,731
Deferred income taxes		1,143		2,723
Regulatory liabilities - current		8,822		13,538
Derivative liabilities		7,131		7,750
Other current liabilities		5,495		6,446
Total Current Liabilities		82,693		95,014
Other Credits:
Deferred income taxes		306,559		279,085
Investment tax credit - deferred		1,274		1,413
Regulatory liabilities		21,970		19,792
Accrued pension and other postretirement benefits		50,338		49,184
Derivative liabilities		47,820		57,930
Other deferred liabilities and other		52,947		52,357
Total Other Credits		480,908		459,761
Capitalization:
Common shareholder's equity		476,408		457,491
Noncontrolling interest		122,389		118,963
Total Equity		598,797		576,454
Long-term debt		396,304		399,414
Total Capitalization		995,101		975,868
Commitments and contingencies (see Footnote 8)		-		-
Total Liabilities and Capitalization	$	1,558,702	$	1,530,643
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

12

Madison Gas and Electric Company

Consolidated Statements of Common Equity (unaudited)

(In thousands)

								Accumulated
					Additional				Other		Non-
	Common Stock				Paid-in		Retained	Comprehensive			Controlling
	Shares		Value		Capital		Earnings	Income			Interest		Total
2013
Beginning balance - Dec. 31, 2012	17,348	$	17,348	$	192,417	$	223,527	$	4	$	117,470	$	550,766
Net income							40,309				20,547		60,856
Other comprehensive income (loss)									77				77
Equity contribution received by
noncontrolling interest											1,065		1,065
Distributions to parent from
noncontrolling interest											(21,148)		(21,148)
Ending balance - September 30, 2013	17,348	$	17,348	$	192,417	$	263,836	$	81	$	117,934	$	591,616
2014
Beginning balance - Dec. 31, 2013	17,348	$	17,348	$	192,417	$	247,534	$	192	$	118,963	$	576,454
Net income							45,471				19,784		65,255
Other comprehensive income (loss)									(54)				(54)
Cash dividends paid to parent
by MGE							(26,500)						(26,500)
Equity contribution received by
noncontrolling interest											1,420		1,420
Distributions to parent from
noncontrolling interest											(17,778)		(17,778)
Ending balance - September 30, 2014	17,348	$	17,348	$	192,417	$	266,505	$	138	$	122,389	$	598,797
The accompanying notes are an integral part of the above unaudited consolidated financial statements.

13

MGE Energy, Inc., and Madison Gas and Electric Company

Notes to Consolidated Financial Statements (unaudited)

September 30, 2014

1.

Basis of Presentation - MGE Energy and MGE.

This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc. and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2013 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of September 30, 2014, and for the three and nine months ended, are unaudited, but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in MGE Energy's and MGE's 2013 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 57 through 100 of the 2013 Annual Report on Form 10-K.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014, to all shareholders of record as of January 24, 2014. All shares and per share data provided in this report give effect to this stock split.

2.

Equity and Financing Arrangements.

a.

Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the nine months ended September 30, 2014 and 2013, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b.

Dilutive Shares Calculation - MGE Energy.

MGE Energy does not hold any dilutive securities.

3.

Investment in ATC - MGE Energy and MGE.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.

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MGE Transco has accounted for its investment in ATC under the equity method of accounting. For the nine months ended September 30, 2014 and 2013, MGE Transco recorded the following:

		Nine Months Ended
		September 30,
(In thousands)		2014		2013
Equity in earnings from investment in ATC	$	7,306	$	7,045
Dividends received from ATC		5,762		5,498
Capital contributions to ATC		1,420		1,065

On October 31, 2014, MGE Transco made an additional $0.4 million capital contribution to ATC.

MGE Transco's investment in ATC as of September 30, 2014, and December 31, 2013, was $67.5 million and $64.5 million, respectively.

At September 30, 2014, MGE is the majority owner, and MGE Energy, the holding company, is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as noncontrolling interest.

ATC's summarized financial data for the three and nine months ended September 30, 2014 and 2013, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Operating revenues	$	163,643	$	160,480	$	486,970	$	464,345
Operating expenses		(76,561)		(77,595)		(229,589)		(217,240)
Other income, net		693		917		1,403		585
Interest expense, net		(22,204)		(21,136)		(66,442)		(63,232)
Earnings before members' income taxes	$	65,571	$	62,666	$	192,342	$	184,458

4.

Columbia Environmental Project Construction - MGE Energy and MGE.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. WPSC owns a 31.8% interest, and MGE owns a 22% interest, in Columbia. In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and baghouses and associated equipment on Columbia Units 1 and 2 to reduce SO₂ and mercury emissions. The modifications to Unit 2 were placed into service in April 2014, and the modifications to Unit 1 were placed into service in July 2014. The scrubbers and baghouses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR, CSAPR, MATS, and the Wisconsin Mercury Rule. As of September 30, 2014, $138.6 million of the capitalized project was transferred from Construction work in progress to Property, plant, and equipment on MGE's balance sheet related to Units 1 and 2 being placed into service. This total amount consisted of $128.8 million of capital expenditures and $9.8 million of AFUDC. MGE's share of various contractual commitments entered for the project as of September 30, 2014, is $5.5 million. For the three months ended September 30, 2014 and 2013, MGE has recognized after tax $0.1 million and $0.8 million, respectively, in AFUDC equity related to this project. For the nine months ended September 30, 2014 and 2013, MGE has recognized after tax $3.0 million and $1.9 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. For 2014, the PSCW authorized MGE 100% AFUDC on this project during construction. For 2013, the PSCW authorized MGE a 50% current return (included in customer rates) and the remaining 50% as AFUDC.

5.

Taxes - MGE Energy and MGE.

MGE Energy's effective income tax rates for the three and nine months ended September 30, 2014, were 38.0% and 37.8%, respectively, compared to 37.6% and 37.8% for the same periods in 2013. MGE's effective income tax rates for the three and nine months ended September 30, 2014, were 37.9% and 37.8%, respectively, compared to 37.6% and 37.8% for the same periods in 2013. The net increase in the three month effective tax rate is attributable to less AFUDC equity earned during the three month period in 2014 compared to 2013.

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6.

Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months ended September 30, 2014 and 2013. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,536	$	1,924	$	4,609	$	5,764
Interest cost		3,367		3,178		10,102		9,521
Expected return on assets		(5,467)		(4,764)		(16,402)		(14,273)
Amortization of:
Prior service cost		51		79		152		237
Actuarial loss		180		2,011		539		6,023
Net periodic (benefit) cost	$	(333)	$	2,428	$	(1,000)	$	7,272
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	241	$	594	$	722	$	1,781
Interest cost		564		966		1,691		2,898
Expected return on assets		(478)		(542)		(1,432)		(1,626)
Amortization of:
Transition obligation		1		-		2		2
Prior service (benefit) cost		(487)		28		(1,462)		83
Actuarial loss		28		310		86		930
Net periodic (benefit) cost	$	(131)	$	1,356	$	(393)	$	4,068

7.

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy's Performance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

In addition to units granted in 2009 through 2013, on February 21, 2014, 21,991 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule and reflect the three-for-two stock split declared December 20, 2013. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30, 2014, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

16

During the nine months ended September 30, 2014 and 2013, MGE recorded $0.9 million and $1.1 million, respectively, in compensation expense as a result of the plans. In January 2014, cash payments of $1.2 million were distributed relating to awards that were granted in 2009. No forfeitures occurred during the nine months ended September 30, 2014 or 2013. At September 30, 2014, $3.7 million of outstanding awards are vested.

8.

Commitments and Contingencies - MGE Energy and MGE.

a.

Environmental.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. These initiatives, proposed rules, and court challenges include:

·

The President's announced plan and directive to the EPA to regulate carbon pollution, or greenhouse gas (GHG) emissions, from new and existing electric power generation units, and the EPA's related proposed GHG New Source Performance Standards (NSPS) (see below for additional information on the NSPS rule).

·

Rules to regulate NO_x and SO₂ emissions, including the EPA's Cross State Air Pollution Rule (CSAPR) (see below for recent developments with CSAPR). An environmental group has sought federal appellate court review of the EPA's Clean Air Visibility Rule (CAVR) to address regional haze. Both the pending challenges to CSAPR and the appellate court review of CAVR make the nature of compliance requirements uncertain.

·

Rules to regulate mercury and similar emissions, including Wisconsin's adopted Mercury Rule and the EPA's adopted Mercury and Air Toxics Standards.

·

The EPA's cooling water intake rules. The EPA issued a final rule for existing facilities in May 2014. The final rule is discussed below.

·

The EPA's proposed water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants from coal-burning plants such as Columbia and the Elm Road Units.

·

The EPA's ongoing review of several National Ambient Air Quality Standards (NAAQS), including the potential lowering of the ozone NAAQS and its proposed requirements for air agencies to characterize sulfur dioxide air quality for purposes of implementing the 1-hour SO₂ NAAQS. This approach focuses on large sources of SO₂ emissions and proposes area designations to be made in two rounds (2017 and 2020). The proposed rule gives states broad discretion in its implementation. The final rule is expected late in 2014. MGE will be reviewing the rule for potential impacts on its operations.

The matters in the bullet points above are discussed further in Footnote 18.d. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2013 Annual Report on Form 10-K. In addition to the developments noted above, the following discussion is an update to the current status of environmental matters set forth in that Footnote.

EPA's Final 316(b) Rule Governing Water Intake Systems at Electric Generating Facilities

In August 2014, the EPA published its Phase II and III Rules pursuant to Section 316(b) of the Clean Water Act, which governs cooling water intake structures located at large existing power plant and industrial facilities. The 316(b) Rule requires these facilities to implement methods for reducing fish impingement by their water intakes using one of seven options, including closed cycle cooling (CCC) systems.

Our WCCF facility already employs a CCC system as defined under the Rule. The Columbia plant may need to address multiple intake structures. Our Blount plant has conducted studies regarding options for compliance with this rule. The exact requirements at Blount and Columbia, however, will not be known until those sites' permits are modified to account for this rule. Nonetheless, MGE expects that the 316(b) Rule will not have material effects on its existing plants.

17

EPA's Cross-State Air Pollution Rule (CSAPR) Upheld by the Supreme Court

On April 29, 2014, the US Supreme Court issued a decision reversing the D.C. Circuit Court's decision that had vacated CSAPR and remanding the matter back to the D.C. Circuit for further proceedings. At that time CSPAR remained subject to an order of the D.C. Circuit that stayed its implementation. On October 23, 2014, the D.C. Circuit lifted its stay of CSAPR and set a briefing schedule to resolve issues remaining in the lawsuit. The court also set the briefing schedule for ongoing litigation with oral arguments scheduled for March 2015. The State of Wisconsin has filed a motion with the D.C. Circuit Court reiterating its contention that Wisconsin be removed from CSAPR and may be a part of the court's briefing and oral argument schedule. With several issues undecided and court proceedings extending into 2015, there is remaining uncertainty as to whether MGE's facilities will be required to meet the CSAPR mandates and, if so, the deadline for achieving compliance. The Clean Air Interstate Rule (CAIR) remains in effect for the time being. See MGE Energy's and MGE's 2013 Annual Report on Form 10K for additional information on the legal proceedings associated with these environmental matters.

With CSAPR now reinstated, it will require (once implemented) that qualifying power plants meet SO₂ and NO_x allocations or purchase them on the market. MGE has been monitoring our overall compliance options, particularly at our Columbia power plant as we awaited installation and testing of SO₂ controls. With the 2014 installation of SO₂ pollution controls at Columbia, we will likely meet or exceed the allocations for Columbia based on the CSAPR allocations in the current rule (see Footnote 4 for information regarding the Columbia environmental construction project and below in this Footnote for information regarding our consent decree). MGE expects that the costs pertaining to meeting CSAPR and the consent decree requirements will be fully recoverable through rates. We will continue to monitor and evaluate the D.C. Circuit Court remand proceedings and the implementation of the rule by the EPA and WDNR.

EPA's Greenhouse Gas Reduction Guidelines under the Clean Air Act 111(d) Rule

On June 2, 2014, the EPA released proposed guidelines for states to use in developing plans to control GHG emissions from existing fossil fuel fired electric generating units (EGUs). The proposed rule was published in the Federal Register on June 17, 2014.

The EPA's proposal seeks to reduce GHG emissions from EGUs by a national average of 30% by 2030 as measured from a 2005 baseline. Each state is given its own emission reduction targets to meet this goal. These targets are expressed as a "rate-based" emission average to be achieved by the combined fleet of EGUs within the state. States would be expected to make "meaningful progress" towards these reductions by 2020 and to meet their respective targets by 2030.

The EPA's proposal establishes guidelines for states and encourages the use of four "building blocks" for achieving these reductions. These "building blocks" are: (1) increasing the efficiency of EGUs; (2) re-dispatching of gas-fired generation at the expense of coal; (3) expanding the use of low and no carbon power sources, such as wind, nuclear and solar; and (4) improving demand side energy efficiency to reduce electric use.

The EPA is taking comments on the proposed rule through December 1, 2014. The rule is expected to be finalized by June 2015. States will then have up to two years to prepare compliance plans. This rule could have significant impacts on EGUs. MGE is reviewing the proposal at this time.

Coal Combustion Residual Rule

The EPA's proposed Coal Combustion Residual (CCR) Rule is anticipated to be finalized in December 2014. The final CCR Rule will regulate disposal and management of ash and other coal combustion byproducts as a waste under the EPA's solid waste rules.

Columbia

Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia as noted below.

Columbia Environmental Project

See Footnote 4 for information regarding the Columbia environmental construction project.

18

Columbia Clean Air Act Litigation

In December 2009, the EPA sent a notice of violation (NOV) to MGE and the other co-owners of Columbia. The NOV alleged that WPL, as owner-operator, and the other co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the PSD program requirements, the Title V operating permit requirements of the CAA and the Wisconsin State Implementation Plan (SIP). In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, Sierra Club filed lawsuits against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities.

In April 2013, WPL, as owner-operator, along with the other owners of Columbia, entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. In June 2013, the consent decree was approved and entered by the Court. The consent decree requires installation of the following emission controls at Columbia: SO₂ scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014, which have now been installed, and an SCR system at Columbia Unit 2 by December 31, 2018. In addition, the consent decree establishes emission rate limits for SO₂, NO_x, and particulate matter for Columbia Units 1 and 2. The consent decree also includes annual plant-wide emission caps for SO₂ and NO_x for Columbia. MGE also paid approximately $0.2 million as its share of a civil penalty and will complete approximately $0.6 million in environmental mitigation projects. MGE intends to seek recovery in rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b.

Chattel Paper Agreement and Other Guarantees.

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2015. At September 30, 2014, MGE had sold a $4.1 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of September 30, 2014, the servicing asset recognized by MGE is $0.2 million.

MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.

MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at September 30, 2014, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan. Principal payments for the remainder of 2014 and the next four years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Chattel Paper	$	108	$	921	$	841	$	438	$	374

c.

Legal Matters.

MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements.

19

d.

Purchase Contracts.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of September 30, 2014, the future commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Coal(a)	$	11,950	$	18,439	$	10,765	$	5,073	$	2,710
Natural gas
Transportation & storage(b)		5,234		18,073		9,937		272		191
Supply(c)		16,951		16,070		-		-		-
Purchase power(d)		12,665		48,964		49,633		50,132		51,153
Other		16,102		-		-		-		-
	$	62,902	$	101,546	$	70,335	$	55,477	$	54,054

(a)

Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurements for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, who are the operators of those facilities. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)

MGE's natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

(c)

These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

(d)

MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates.

e.

Elm Road - MGE Energy and MGE.

The warranty periods for both of the Elm Road Units have expired. During 2013, WEPCO and Bechtel (the construction contractor for the Elm Road Units) were working through the outstanding warranty claims. The warranty claim for the costs incurred to repair steam turbine corrosion damage identified on both units was resolved through a binding arbitration in June 2013. Final acceptance of the Elm Road Units occurred in June 2013 after all requirements stated in the contract with Bechtel were satisfied. In April 2014, an additional warranty claim was resolved that did not have a material impact on our financial statements. The parties continue to work through one potential remaining warranty claim.

9.

Derivative and Hedging Instruments - MGE Energy and MGE.

a.

Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices and gas revenues. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

20

b.

Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2014	December 31, 2013
Commodity derivative contracts	447,570 MWh	458,660 MWh
Commodity derivative contracts	6,555,000 Dth	3,750,000 Dth
FTRs	3,104 MW	1,984 MW

c.

Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market, MGE holds FTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. At September 30, 2014, and December 31, 2013, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.3 million and $1.8 million, respectively.

MGE is a party to a ten-year purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at September 30, 2014, and December 31, 2013, reflects a loss position of $54.9 million and $65.7 million, respectively. The actual fuel cost will be recognized in purchased power expense in the month of purchase and collected in rates.

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheet. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral. At September 30, 2014, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $0.6 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2014
Commodity derivative contracts	Other current assets	$	1,507	Derivative liability (current)	$	532
Commodity derivative contracts	Other deferred charges		48	Derivative liability (long-term)		4
FTRs	Other current assets		1,237	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,120
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		47,820
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930

21

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2014
Commodity derivative contracts	$	1,555	$	(525)	$	-	$	1,030
FTRs		1,237		-		-		1,237
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2014
Commodity derivative contracts	$	536	$	(525)	$	-	$	11
Ten-year PPA		54,940		-		-		54,940
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at September 30, 2014 and 2013, and the consolidated income statement for the three and nine months ended September 30, 2014 and 2013.

		2014				2013
(In thousands)		Current and long-term regulatory asset		Other current assets		Current and long-term regulatory asset		Other current assets
Three Months Ended September 30:
Balance at July 1,	$	48,853	$	676	$	66,649	$	658
Change in unrealized loss		5,329		-		2,330		-
Realized gain (loss) reclassified to a deferred
account		(314)		314		(275)		275
Realized gain (loss) reclassified to income
statement		(1,184)		(249)		(621)		(111)
Balance at September 30,	$	52,684	$	741	$	68,083	$	822
Nine Months Ended September 30:
Balance at January 1,	$	63,893	$	411	$	72,329	$	574
Change in unrealized gain		(18,090)		-		(1,330)		-
Realized gain (loss) reclassified to a deferred
account		1,120		(1,120)		(953)		953
Realized gain (loss) reclassified to income
statement		5,761		1,450		(1,963)		(705)
Balance at September 30,	$	52,684	$	741	$	68,083	$	822

22

		Realized losses (gains)
		2014				2013
(In thousands)		Fuel for electric generation/ purchased power		Cost of gas sold		Fuel for electric generation/ purchased power		Cost of gas sold
Three Months Ended September 30:
Commodity derivative contracts	$	480	$	(18)	$	(7)	$	-
FTRs		(97)		-		(387)		-
Ten-year PPA		1,068		-		1,126		-
Nine Months Ended September 30:
Commodity derivative contracts	$	(5,376)	$	(1,367)	$	(523)	$	608
FTRs		(929)		-		(896)		-
Ten-year PPA		461		-		3,479		-

MGE's commodity derivative contracts, FTRs, and ten-year PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheet and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.

The ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0 million, depending on MGE's nominated capacity amount. As of September 30, 2014, no collateral has been posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30, 2014, certain counterparties were in a net liability of less than $0.1 million. As of December 31, 2013, no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30, 2014, no counterparties have defaulted.

10.

Rate Matters - MGE Energy and MGE.

a.

Rate Proceedings.

On April 17, 2014, MGE filed an application with the PSCW requesting a 2.8% increase to electric rates and a 2.3% decrease to gas rates for 2015. MGE has requested escrow accounting treatment for transmission related costs starting in 2015. This treatment will allow MGE to reflect any differential between costs reflected in rates and actual costs incurred in its next rate case filing. The proposed electric rate increases cover costs associated with the construction of emission-reduction equipment at Columbia and improvements and reliability of the state's electric transmission system.

During the rate case proceeding, certain updates have been made to reflect changing conditions from the initial filing. Those updates include increased costs for fuel and purchased power costs primarily related to coal delivery costs, lower transmission costs due to favorable FERC decisions on cost allocations for system reliability payments, and increased costs to reflect current market conditions for pension and post-retirement benefit costs. Incorporating the revisions would adjust the electric rate increase from 2.8% to 4.3% and adjust the gas rate decrease from 2.3% to 1.4%. A PSCW decision is expected by the end of 2014.

On July 26, 2013, the PSCW authorized MGE to freeze electric and natural gas rates at 2013 levels for 2014. The order includes authorizing 100% AFUDC on the Columbia scrubber construction project and deferral of increased costs related to ATC and MISO Schedule 26 fees. As part of the rate freeze plan authorized by the PSCW, effective January 1, 2014, approximately $6.2 million associated with a 2012 fuel rule surplus credit will not be required to be refunded to customers and will be amortized in 2014. The fuel credit will accrue interest at MGE's weighted cost of capital. The authorized return on equity remained unchanged at 10.3%.

23

On December 14, 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million and to increase gas rates by 1.0% or $1.6 million. The change in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. The authorized return on common stock equity remained unchanged at 10.3%.

b.

Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

As of September 30, 2014, MGE did not defer any 2014 electric fuel-related savings/costs that are outside the range authorized by the PSCW. As part of the rate freeze plan authorized by the PSCW for 2014, $4.7 million of the approximately $6.2 million associated with the 2012 fuel rule surplus credit was amortized against purchased power expense during the nine months ended September 30, 2014. The 2013 fuel rule surplus credit of $6.7 million was returned to customers in October 2014.

11.

Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

a.

Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.

At September 30, 2014, and December 31, 2013, the carrying amount of cash and cash equivalents approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30, 2014, and December 31, 2013. Since long-term debt is not traded in an active market, it is classified as Level 2. The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

24

		September 30, 2014				December 31, 2013
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	88,719	$	88,719	$	68,813	$	68,813
Liabilities:
Long-term debt*		400,724		443,203		403,793		432,010
MGE
Assets:
Cash and cash equivalents	$	22,983	$	22,983	$	14,808	$	14,808
Liabilities:
Long-term debt*		400,724		443,203		403,793		432,010
*Includes long-term debt due within one year.

b.

Recurring Fair Value Measurements.

The following table presents the balances of assets and liabilities measured at fair value on a recurring basis for MGE Energy and MGE.

		Fair Value as of September 30, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	2,267	$	417	$	-	$	1,850
Exchange-traded investments		886		886		-		-
Total Assets	$	3,153	$	1,303	$	-	$	1,850
Liabilities:
Derivatives, net	$	54,951	$	-	$	-	$	54,951
Deferred compensation		2,705		-		2,705		-
Total Liabilities	$	57,656	$	-	$	2,705	$	54,951
MGE
Assets:
Derivatives, net	$	2,267	$	417	$	-	$	1,850
Exchange-traded investments		341		341		-		-
Total Assets	$	2,608	$	758	$	-	$	1,850
Liabilities:
Derivatives, net	$	54,951	$	-	$	-	$	54,951
Deferred compensation		2,705		-		2,705		-
Total Liabilities	$	57,656	$	-	$	2,705	$	54,951

25

		Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(a)	$	1,787	$	735	$	-	$	1,052
Exchange-traded investments		792		792		-		-
Total Assets	$	2,579	$	1,527	$	-	$	1,052
Liabilities:
Derivatives, net	$	65,680	$	-	$	-	$	65,680
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	68,044	$	-	$	2,364	$	65,680
MGE
Assets:
Derivatives, net(a)	$	1,787	$	735	$	-	$	1,052
Exchange-traded investments		431		431		-		-
Total Assets	$	2,218	$	1,166	$	-	$	1,052
Liabilities:
Derivatives, net	$	65,680	$	-	$	-	$	65,680
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	68,044	$	-	$	2,364	$	65,680
(a)   These amounts are shown gross and exclude $0.2 million of collateral that was
posted against derivative positions with counterparties as of  December 31, 2013.

No transfers were made in or out of Level 1 or Level 2 for the nine months ended September 30, 2014.

Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore considered unobservable and classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease and if the basis adjustment is increased, the fair value measurement will increase.

The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.

26

This model is prepared by members of MGE's Energy Accounting group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

The following table presents the significant unobservable inputs used in the pricing model.

	Model Input
Significant Unobservable Inputs	September 30, 2014	December 31, 2013
Basis adjustment:
On peak	97.5%	94.2%
Off peak	94.4%	92.6%
Counterparty fuel mix:
Internal generation	50% - 70%	50% - 70%
Purchased power	50% - 30%	50% - 30%

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Beginning balance	$	(49,349)	$	(66,856)	$	(64,628)	$	(72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(3,752)		(1,472)		11,528		4,018
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,419)		(174)		5,837		(2,034)
Included in current assets		-		(38)		(89)		(94)
Purchases		6,371		6,052		19,900		17,709
Sales		-		-		(60)		(2)
Issuances		-		-		-		-
Settlements		(4,952)		(5,840)		(25,589)		(15,579)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(53,101)	$	(68,328)	$	(53,101)	$	(68,328)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(b)	$	-	$	-	$	-	$	-

The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE (b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Purchased Power Expense	$	(1,411)	$	(174)	$	5,845	$	(2,034)
Cost of Gas Sold Expense		(8)		-		(8)		-
Total	$	(1,419)	$	(174)	$	5,837	$	(2,034)

(b)

MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.

27

12.

New Accounting Pronouncements - MGE Energy and MGE.

a.

Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance became effective January 1, 2014. The authoritative guidance did not have a financial or disclosure impact.

b.

Presentation of an Unrecognized Tax Benefit.

In July 2013, the FASB issued authoritative guidance within the Codification's Income Statement topic that provides guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The authoritative guidance was issued to eliminate diversity in practice by providing guidance on the presentation of unrecognized tax benefits. This authoritative guidance became effective January 1, 2014. The authoritative guidance will not have a financial statement or disclosure impact, unless MGE Energy or its subsidiaries are in a net operating loss position. MGE Energy or its subsidiaries are currently not in a net operating loss position.

c.

Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2017. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

d.

Transfers and Servicing Assets.

In June 2014, the FASB issued authoritative guidance within the Codification's Transfers and Servicing topic that provides guidance on the accounting and disclosures for repurchase-to-maturity transactions, securities lending transactions, and repurchase financings. This authoritative guidance will become effective January 1, 2015. The authoritative guidance will change the accounting for the Chattel Paper program. Prior to adoption of the standard, Chattel Paper was treated as an off-balance sheet arrangement. Upon adoption, assets and liabilities will increase approximately $4.0 million and additional disclosures will be required. The cumulative impact of this guidance on our financial statements is not expected to be material.

13.

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See MGE Energy's and MGE's 2013 Annual Report on Form 10-K for additional discussion of each of these segments.

28

The following tables show segment information for MGE Energy's operations for the indicated periods:

(In thousands) MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2014
Operating revenues	$	112,869	$	21,404	$	862	$	-	$	-	$	-	$	135,135
Interdepartmental revenues		156		1,614		10,674		-		-		(12,444)		-
Total operating revenues		113,025		23,018		11,536		-		-		(12,444)		135,135
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		(12)		-		(10,376)
Other operating expenses		(74,573)		(22,199)		(35)		-		(276)		12,444		(84,639)
Operating income (loss)		31,521		(756)		9,643		-		(288)		-		40,120
Other income, net		136		8		-		2,423		69		-		2,636
Interest (expense) income, net		(2,832)		(808)		(1,545)		-		44		-		(5,141)
Income (loss) before taxes		28,825		(1,556)		8,098		2,423		(175)		-		37,615
Income tax (provision) benefit		(10,758)		651		(3,251)		(963)		35		-		(14,286)
Net income (loss)	$	18,067	$	(905)	$	4,847	$	1,460	$	(140)	$	-	$	23,329
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		-		(9,710)
Other operating expenses		(82,414)		(21,485)		(33)		(1)		(145)		13,589		(90,489)
Operating income (loss)		31,169		(1,361)		10,238		(1)		(145)		-		39,900
Other income, net		1,166		92		-		2,340		152		-		3,750
Interest (expense) income, net		(2,309)		(729)		(1,596)		-		29		-		(4,605)
Income (loss) before taxes		30,026		(1,998)		8,642		2,339		36		-		39,045
Income tax (provision) benefit		(11,021)		751		(3,469)		(939)		(14)		-		(14,692)
Net income (loss)	$	19,005	$	(1,247)	$	5,173	$	1,400	$	22	$	-	$	24,353
Nine Months Ended September 30, 2014
Operating revenues	$	308,418	$	163,335	$	2,392	$	-	$	-	$	-	$	474,145
Interdepartmental revenues		401		7,130		32,017		-		-		(39,548)		-
Total operating revenues		308,819		170,465		34,409		-		-		(39,548)		474,145
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		(35)		-		(30,191)
Other operating expenses		(229,286)		(144,907)		(105)		-		(672)		39,548		(335,422)
Operating income (loss)		59,624		20,858		28,757		-		(707)		-		108,532
Other (deductions) income, net		2,999		(44)		-		7,306		475		-		10,736
Interest (expense) income, net		(7,571)		(2,429)		(4,676)		-		126		-		(14,550)
Income (loss) before taxes		55,052		18,385		24,081		7,306		(106)		-		104,718
Income tax provision		(19,602)		(7,378)		(9,665)		(2,924)		(16)		-		(39,585)
Net income (loss)	$	35,450	$	11,007	$	14,416	$	4,382	$	(122)	$	-	$	65,133
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		-		(28,864)
Other operating expenses		(235,390)		(111,494)		(96)		(1)		(537)		42,783		(304,735)
Operating income (loss)		56,057		15,971		30,535		(1)		(537)		-		102,025
Other income, net		2,226		69		-		7,045		430		-		9,770
Interest (expense) income, net		(7,028)		(2,166)		(4,814)		-		71		-		(13,937)
Income (loss) before taxes		51,255		13,874		25,721		7,044		(36)		-		97,858
Income tax (provision) benefit		(18,148)		(5,844)		(10,209)		(2,837)		8		-		(37,030)
Net income (loss)	$	33,107	$	8,030	$	15,512	$	4,207	$	(28)	$	-	$	60,828

29

The following tables show segment information for MGE's operations for the indicated periods:

(In thousands) MGE		Electric		Gas		Nonregulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2014
Operating revenues	$	112,875	$	21,410	$	862	$	-	$	-	$	135,147
Interdepartmental revenues		150		1,608		10,674		-		(12,432)		-
Total operating revenues		113,025		23,018		11,536		-		(12,432)		135,147
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		-		(10,364)
Other operating expenses*		(85,314)		(21,544)		(3,286)		-		12,432		(97,712)
Operating income (loss)*		20,780		(101)		6,392		-		-		27,071
Other income, net*		119		4		-		1,460		-		1,583
Interest expense, net		(2,832)		(808)		(1,545)		-		-		(5,185)
Net income (loss)		18,067		(905)		4,847		1,460		-		23,469
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,653)		(6,653)
Net income (loss) attributable to MGE	$	18,067	$	(905)	$	4,847	$	1,460	$	(6,653)	$	16,816
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		(9,710)
Other operating expenses*		(93,481)		(20,748)		(3,502)		(1)		13,589		(104,143)
Operating income (loss)*		20,102		(624)		6,769		(1)		-		26,246
Other income, net*		1,212		106		-		1,401		-		2,719
Interest expense, net		(2,309)		(729)		(1,596)		-		-		(4,634)
Net income (loss)		19,005		(1,247)		5,173		1,400		-		24,331
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,861)		(6,861)
Net income (loss) attributable to MGE	$	19,005	$	(1,247)	$	5,173	$	1,400	$	(6,861)	$	17,470
Nine Months Ended September 30, 2014
Operating revenues	$	308,435	$	163,351	$	2,392	$	-	$	-	$	474,178
Interdepartmental revenues		384		7,114		32,017		-		(39,515)		-
Total operating revenues		308,819		170,465		34,409		-		(39,515)		474,178
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		-		(30,156)
Other operating expenses*		(248,525)		(152,182)		(9,770)		-		39,515		(370,962)
Operating income*		40,385		13,583		19,092		-		-		73,060
Other (deductions) income, net*		2,636		(147)		-		4,382		-		6,871
Interest expense, net		(7,571)		(2,429)		(4,676)		-		-		(14,676)
Net income		35,450		11,007		14,416		4,382		-		65,255
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,784)		(19,784)
Net income attributable to MGE	$	35,450	$	11,007	$	14,416	$	4,382	$	(19,784)	$	45,471
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		(28,864)
Other operating expenses*		(253,566)		(117,346)		(10,305)		(1)		42,783		(338,435)
Operating income (loss)*		37,881		10,119		20,326		(1)		-		68,325
Other income, net*		2,254		77		-		4,208		-		6,539
Interest expense, net		(7,028)		(2,166)		(4,814)		-		-		(14,008)
Net income		33,107		8,030		15,512		4,207		-		60,856
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(20,547)		(20,547)
Net income attributable to MGE	$	33,107	$	8,030	$	15,512	$	4,207	$	(20,547)	$	40,309
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

30

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:

		Utility						Consolidated
(In thousands) MGE Energy		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2014	$	914,839	$	263,688	$	30,962	$	307,599	$	67,476	$	443,898	$	(408,566)	$	1,619,896
December 31, 2013		899,257		265,694		19,853		288,116		64,504		431,436		(389,800)		1,579,060
Capital Expenditures:
Nine Months Ended September 30, 2014	$	50,033	$	14,599	$	-	$	1,506	$	-	$	-	$	-	$	66,138
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		-		119,047

		Utility						Consolidated
(In thousands) MGE		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Elimination Entries		Total
Assets:
September 30, 2014	$	917,503	$	262,237	$	30,778	$	286,600	$	67,476	$	(5,892)	$	1,558,702
December 31, 2013		899,257		265,694		19,853		288,066		64,504		(6,731)		1,530,643
Capital Expenditures:
Nine Months Ended September 30, 2014	$	50,033	$	14,599	$	-	$	1,506	$	-	$	-	$	66,138
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		119,047

31

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

General

MGE Energy is an investor-owned public utility holding company operating through subsidiaries in five business segments:

·

Regulated electric utility operations, conducted through MGE,

·

Regulated gas utility operations, conducted through MGE,

·

Nonregulated energy operations, conducted through MGE Power and its subsidiaries,

·

Transmission investments, representing our equity investment in ATC, and

·

All other, which includes corporate operations and services.

Our principal subsidiary is MGE, which generates and distributes electric energy, distributes natural gas, and represents a majority portion of our assets, liabilities, revenues, and expenses. MGE generates and distributes electricity to approximately 141,000 customers in Dane County, Wisconsin, including the city of Madison, and purchases and distributes natural gas to approximately 147,000 customers in the Wisconsin counties of Columbia, Crawford, Dane, Iowa, Juneau, Monroe, and Vernon.

Our nonregulated energy operations own interests in electric generating capacity that is leased to MGE. The ownership/leasing structure was adopted under applicable state regulatory guidelines for MGE's participation in these generation facilities, consisting principally of a stable return on the equity investment in the new generation facilities over the term of the related leases. The nonregulated energy operations include an ownership interest in two coal-fired generating units in Oak Creek, Wisconsin and a partial ownership of a cogeneration project on the UW-Madison campus. A third party operates the units in Oak Creek, and MGE operates the cogeneration project. Due to the nature of MGE's participation in these facilities, the results of our nonregulated operations are also consolidated into MGE's consolidated financial position and results of operations under applicable accounting standards.

Executive Overview

Our primary focus today and for the foreseeable future is our core utility customers at MGE as well as creating long-term value for our shareholders. MGE continues to face the challenge of providing its customers with reliable power at competitive prices. MGE meets this challenge by investing in more efficient generation projects, including renewable energy sources. MGE will continue to focus on growing earnings while controlling operating and fuel costs. MGE maintains safe and efficient operations in addition to providing customer value. We believe it is critical to maintain a strong credit standing consistent with financial strength in MGE as well as the parent company in order to accomplish these goals.

We earn our revenue and generate cash from operations by providing electric and natural gas utility services, including electric power generation and electric power and gas distribution. The earnings and cash flows from the utility business are sensitive to various external factors, including:

·

Weather, and its impact on customer sales of electricity and gas,

·

Economic conditions, including current business activity and employment and their impact on customer demand,

·

Regulation and regulatory issues, and their impact on the timing and recovery of costs,

·

Energy commodity prices,

·

Equity price risk pertaining to pension related assets,

·

Credit market conditions, including interest rates and our debt credit rating,

·

Environmental laws and regulations, including adopted and pending environmental rule changes,

and other factors listed in "Item 1A. Risk Factors" in our 2013 Annual Report on Form 10-K and in this report.

For the three months ended September 30, 2014, MGE Energy's earnings were $23.3 million or $0.67 per share compared to $24.4 million or $0.70 per share for the same period in the prior year. MGE's earnings for the three months ended September 30, 2014, were $16.8 million compared to $17.5 million for the same period in the prior year.

For the nine months ended September 30, 2014, MGE Energy's earnings were $65.1 million or $1.88 per share compared to $60.8 million or $1.75 per share for the same period in the prior year. MGE's earnings for the nine months ended September 30, 2014, were $45.5 million compared to $40.3 million for the same period in the prior year.

32

MGE Energy's income was derived from our business segments as follows:

		Three Months Ended				Nine Months Ended
(In thousands)		September 30,				September 30,
Business Segment:		2014		2013		2014		2013
Electric Utility	$	18,067	$	19,005	$	35,450	$	33,107
Gas Utility		(905)		(1,247)		11,007		8,030
Nonregulated Energy		4,847		5,173		14,416		15,512
Transmission Investments		1,460		1,400		4,382		4,207
All Other		(140)		22		(122)		(28)
Net Income	$	23,329	$	24,353	$	65,133	$	60,828

Our net income during the three months ended September 30, 2014, compared to the same period in the prior year primarily reflects the effects of the following factors:

·

Electric net income decreased due to a 4.4% decrease in electric retail sales reflecting lower customer demand. Cooling degree days (a measure for determining the impact of weather during the cooling season) decreased by 25.1% compared to the prior year. In addition, AFUDC equity decreased $0.7 million (after tax) related to the Columbia environmental project compared to the same period in the prior year. The Columbia units were placed into service in April 2014 and July 2014. The decrease in electric retail sales was partially offset by savings from operating and maintenance expenditures.

·

Lower non-regulated revenues in 2014 due to the approved recovery, as part of the WEPCO 2013 Wisconsin rate case, of certain one-time force majeure costs associated with the Elm Road Units including a one-time cumulative adjustment for prior periods all recognized in 2013.

Our net income during the nine months ended September 30, 2014, primarily reflects the effects of the following factors:

·

Electric net income increased due to a $1.1 million (after tax) increase in AFUDC equity related to the Columbia environmental project compared to the same period in the prior year. In addition, operating and maintenance expenditures decreased compared to the prior period.

·

Gas net income increased due to a 14.6% increase in gas retail sales reflecting higher customer demand due to a colder winter. The average temperatures in January and February were 11.5 degrees and 12.5 degrees, respectively, compared to 21.8 degrees and 21.3 degrees in the prior year. Heating degree days (a measure for determining the impact of weather during the heating season) increased by 9.2% compared to the prior year. In addition, operating and maintenance expenditures decreased over the prior year.

·

Lower non-regulated revenues in 2014 due to the approved recovery, as part of the WEPCO 2013 Wisconsin rate case, of certain one-time force majeure costs associated with the Elm Road Units including a one-time cumulative adjustment for prior periods all recognized in 2013.

During the first nine months of 2014, the following events occurred:

Columbia Environmental Project: In early 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. These systems and equipment for Unit 2 and Unit 1 were placed into service in April 2014 and July 2014, respectively. As of September 30, 2014, $128.8 million of the capitalized project (excluding carrying costs) was transferred from Construction work in progress to Property, plant, and equipment on MGE's balance sheet related to Unit 1 and Unit 2 being placed into service. MGE has accumulated $7.9 million of capital expenditures and recognized $3.0 million (after tax) in AFUDC equity related to this project for the nine months ended September 30, 2014.

In the near term, several items may affect us, including:

2015 Rate Filing: On April 17, 2014, MGE filed an application with the PSCW requesting a 2.8% increase to electric rates and a 2.3% decrease to gas rates for 2015. MGE has requested escrow accounting treatment for transmission related costs starting in 2015. This treatment will allow MGE to reflect any differential between the costs reflected in rates and actual costs incurred in its next rate case filing. The proposed electric rate increases cover costs associated with the construction of emission-reduction equipment at Columbia and improvements and reliability of the state's electric transmission system.

33

During the rate case proceeding, certain updates have been made to reflect changing conditions from the initial filing. Those updates include increased costs for fuel and purchased power costs primarily related to coal delivery costs, lower transmission costs due to favorable FERC decisions on cost allocations for system reliability payments, and increased costs to reflect current market conditions for pension and post-retirement benefit costs. Incorporating the revisions would adjust the electric rate increase from 2.8% to 4.3% and adjust the gas rate decrease from 2.3% to 1.4%. A PSCW decision is expected by the end of 2014.

Environmental Initiatives: There are proposed legislation, rules, and initiatives involving matters related to air emissions, water effluent, hazardous materials, and greenhouse gases, all of which affect generation plant capital expenditures and operating costs as well as future operational planning. Such legislation and rulemaking could significantly affect the costs of owning and operating fossil-fueled generating plants, such as Columbia and Elm Road, from which we derive approximately 44% of our electric generating capacity. We would expect to seek and receive recovery of any such costs in rates; however, it is difficult to estimate the amount of such costs due to the uncertainty as to the timing and form of the legislation and rules, and the scope and time of the recovery of costs in rates. In addition, the Columbia owners, including MGE, resolved claims surrounding the alleged failure, among other things, to obtain necessary air permits and implement necessary emission controls associated with past activities at Columbia, which will require the installation of additional emission controls at Columbia. See Columbia discussion in Footnote 8.a. in the Notes to Consolidated Financial Statements.

Pension and Other Postretirement Benefit Costs: Costs for pension and other postretirement benefits are affected by actual investment returns on the assets held for those benefits and by the discount rate, which is sensitive to interest rates, used to calculate those benefits. Interest rates have declined since the end of 2013 that could cause discount rates used to value the pension and postretirement benefit obligations to decline. A new set of mortality tables, which are used to develop actuarial estimates, was finalized by the Society of Actuaries in October 2014. The changes in the value of the plan assets, the discount rate, and the mortality tables are not expected to have an impact on the income statement for 2014. However, these changes may increase benefit costs in future years. MGE expects any changes in the cost for employee benefit plans will be factored into future rate actions.

Coal Supplies: Coal supplies at our principal coal-fired generating plants have been affected since the beginning of 2014 by railroad transportation constraints affecting the availability and scheduling of coal transport trains. Reduced on-site supplies could impact the generation available from these units and increase the use of relatively more expensive forms of internal generation or market purchases of external generation from third parties. See Risk Factors in Part II, Item 1A of this report for additional information.

ATC Return on Equity: Several parties have filed a complaint with FERC seeking to reduce the base return on equity (ROE) of MISO and numerous other MISO transmission owners, including ATC, "due to changes in the capital markets." The complaint alleges that the MISO ROE should not exceed 9.15%, the equity components of hypothetical capital structures should be restricted to 50%, and the relevant incentive ROE adders should be discontinued. MISO's base ROE is 12.38% and ATC's base ROE is 12.2%. We derived approximately 7% of our net income for the nine months ended September 30, 2014, from our investment in ATC.

General Economic Conditions: Economic conditions both inside and outside our service area are expected to continue to affect the level of demand for our utility services and may affect the collection of our accounts receivable and the creditworthiness of counterparties with whom we do business. We have in place lines of credit aggregating $150 million for MGE Energy (including MGE) and $100 million for MGE to address our liquidity needs. As of September 30, 2014, there were no borrowings outstanding under our lines of credit.

The following discussion is based on the business segments as discussed in Footnote 13 of the Notes to Consolidated Financial Statements.

34

Three Months Ended September 30, 2014 and 2013

Electric Utility Operations - MGE Energy and MGE

Electric sales and revenues

The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		Three Months Ended September 30,				Three Months Ended September 30,
		2014		2013	% Change	2014	2013	% Change
Residential	$	37,455	$	40,578	(7.7)%	217,677	238,046	(8.6)%
Commercial		60,127		62,582	(3.9)%	488,310	502,924	(2.9)%
Industrial		5,513		5,612	(1.8)%	65,145	66,366	(1.8)%
Other-retail/municipal		10,958		11,952	(8.3)%	118,311	123,221	(4.0)%
Total retail		114,053		120,724	(5.5)%	889,443	930,557	(4.4)%
Sales to the market		179		465	(61.5)%	508	8,038	(93.7)%
Adjustments to revenues		(1,363)		(1,353)	(0.7)%	-	-	-  %
Total	$	112,869	$	119,836	(5.8)%	889,951	938,595	(5.2)%
Cooling degree days (normal 477)						387	517	(25.1)%

Electric operating revenues decreased $7.0 million or 5.8% for the three months ended September 30, 2014, compared to the same period in 2013, due to the following:

(In millions)
Volume	$	(5.3)
Other		(1.4)
Sales to the market		(0.3)
Total	$	(7.0)

In July 2013, the PSCW authorized MGE to freeze 2014 rates at 2013 levels for retail electric customers.

·

Volume. During the three months ended September 30, 2014, there was a 4.4% decrease in total retail sales volumes compared to the same period in the prior year driven by cooler than normal weather.

·

Other. During the three months ended September 30, 2014, other items affecting electric operating revenues decreased $1.4 million primarily attributable to a decrease in demand charges and lower monthly on-peak sales.

·

Sales to the market. Sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may include spot market transactions on the markets operated by MISO and PJM. These sales may also include bilateral sales to other utilities or power marketers. Generating units are dispatched by MISO based on cost considerations as well as reliability of the system. Sales to the market typically occur when MGE has more generation and purchases online than are needed for its own system demand. The excess electricity is then sold to others in the market. For the three months ended September 30, 2014, market volumes decreased compared to the same period in the prior year, reflecting decreased opportunities for sales; however, market settlement resulted in higher revenue per kWh for the three months ended September 30, 2014, reflecting higher market prices.

Electric fuel and purchased power

Electric fuel and purchased power costs reflect a decrease in internal generation volumes offset by an increase in the volume of purchased power when compared to the prior period. Adjustments related to the regulatory recovery for fuel costs, known as fuel rules, moderated the effects of that increased volume. These items are explained below.

35

Fuel for electric generation

The expense for fuel for internal electric generation decreased $4.1 million during the three months ended September 30, 2014, compared to the same period in the prior year, due to the following:

(In millions)
Decrease in volume	$	(4.9)
Increase in per-unit cost		0.8
Total	$	(4.1)

This decrease in expense reflects a 34.9% decrease in internal generated volume delivered to the system primarily as a result of reduced generation at Columbia to reduce coal use in order to maintain inventory levels, partially offset by an 8.2% increase in per-unit cost of internal electric generation.

Purchased power

Purchased power expense decreased $0.7 million during the three months ended September 30, 2014, compared to the same period in the prior year, due to the following:

(In millions)
Increase in volume	$	10.0
Decrease in per-unit cost		(5.1)
Fuel Rules Adjustments
Decrease in recorded fuel rule surplus credit		(4.0)
Amortization of 2012 fuel rule surplus credits		(1.6)
Total	$	(0.7)

The decrease in expense reflects an 18.2% decrease in the per-unit cost of purchased power and a 55.5% increase in the volume of power purchased from third parties primarily as a result of the reduced generation at Columbia.

Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding. Any fuel rules adjustments are reflected in purchased power expense. Cost savings that may be returned to customers are recorded as an increase to purchased power expense, and higher costs that MGE is entitled to recover, after adjustment for excess revenues, are recorded as a reduction to purchased power expense. Any over/under recovery of the deferred costs is determined on an annual basis and adjusted in future billings to customers. During the three months ended September 30, 2014, MGE amortized $1.6 million of the 2012 fuel rule surplus credits. No fuel-related cost savings were deferred during the current period, as compared to $4.0 million of cost savings (surplus credit) in the prior period.

Electric operating and maintenance expenses

Electric operating and maintenance expenses decreased $3.1 million during the three months ended September 30, 2014, compared to the same period in 2013. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(1.5)
Decreased transmission costs		(0.8)
Decreased customer accounts costs		(0.3)
Decreased production expenses		(0.3)
Decreased distribution expenses		(0.2)
Total	$	(3.1)

For the three months ended September 30, 2014, decreased administrative and general costs are primarily due to decreased pension and other postretirement benefit costs.

36

Gas Utility Operations - MGE Energy and MGE

Gas deliveries and revenues

The following table compares MGE's gas revenues and gas therms delivered by customer class during each of the periods indicated:

		Revenues				Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)		Three Months Ended September 30,				Three Months Ended September 30,
		2014		2013	% Change	2014	2013	% Change
Residential	$	9,507	$	8,794	8.1 %	6,105	5,676	7.6 %
Commercial/Industrial		11,188		9,343	19.7 %	18,714	17,789	5.2 %
Total retail		20,695		18,137	14.1 %	24,819	23,465	5.8 %
Gas transportation		608		593	2.5 %	7,127	6,937	2.7 %
Other revenues		101		134	(24.6)%	-	-	-  %
Total	$	21,404	$	18,864	13.5 %	31,946	30,402	5.1 %
Heating degree days (normal 172)						165	157	5.1 %
Average rate per therm of
retail customer	$	0.834	$	0.773	7.9 %

Gas revenues increased $2.5 million or 13.5% for the three months ended September 30, 2014, compared to the same period in 2013. These changes are related to the following factors:

(In millions)
Rate/PGA changes	$	1.5
Volume		1.0
Total	$	2.5

·

Rate/PGA changes. The average retail rate per therm for the three months ended September 30, 2014, increased 7.9% compared to the same period in 2013, reflecting higher natural gas commodity costs. MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas.

·

Volume. For the three months ended September 30, 2014, retail gas deliveries increased 5.8% compared to the same period in 2013, as a result of colder weather compared to warmer weather in the prior year.

Cost of gas sold

For the three months ended September 30, 2014, cost of gas sold increased by $2.2 million, compared to the same period in the prior year. The cost per therm of natural gas increased 17.8%, which resulted in $1.7 million of increased expense. The volume of gas purchased increased 6.2%, which resulted in $0.5 million of increased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $0.6 million for the three months ended September 30, 2014, compared to the same period in 2013. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(0.7)
Decreased production expenses		(0.1)
Decreased customer service costs		(0.1)
Increased distribution expenses		0.3
Total	$	(0.6)

For the three months ended September 30, 2014, decreased administrative and general costs are primarily due to decreased pension and other postretirement benefit costs.

37

Nonregulated Energy Operations - MGE Energy and MGE

For the three months ended September 30, 2014 and 2013, net income at the nonregulated energy operations segment was $4.8 million and $5.2 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road and MGE Power West Campus, which have been formed to own and lease electric generating capacity to assist MGE.

Results reflect the recovery of force majeure costs associated with the construction of the Elm Road Units. In December 2012, as part of WEPCO's (the operator and primary owner of the Elm Road Units) 2013 Wisconsin rate case, the PSCW determined that 100% of the construction costs for the Elm Road Units were prudently incurred, and approved the recovery in rates of more than 99.5% of the force majeure costs. The recovery of the force majeure costs began in 2013, including a one-time cumulative adjustment pertaining to affected periods prior to the PSCW order. The portion pertaining to prior periods was fully reflected in 2013 results.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the three months ended September 30, 2014 and 2013, other income at the transmission investment segment was $2.4 million and $2.3 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 3 of the Notes to Consolidated Financial Statements for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's effective income tax rate for the three months ended September 30, 2014 and 2013, was 38.0% and 37.6%, respectively. MGE's effective income tax rate for the three months ended September 30, 2014 and 2013, was 37.9% and 37.6%, respectively. The net increase is attributable to less AFUDC equity earned during the three month period in 2014 compared to 2013.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, is MGE Energy's interest in MGE Transco, which holds our investment in ATC. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Three Months Ended
		September 30,
(In millions)		2014		2013
MGE Power Elm Road	$	4.1	$	4.3
MGE Power West Campus		1.9		1.9
MGE Transco		0.7		0.6

38

Nine Months Ended September 30, 2014 and 2013

Electric Utility Operations - MGE Energy and MGE

Electric sales and revenues

The following table compares MGE's electric revenues and electric kWh sales by customer class for each of the periods indicated:

		Revenues				Sales (kWh)
(In thousands, except cooling degree days)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2014		2013	% Change	2014	2013	% Change
Residential	$	102,698	$	104,020	(1.3)%	616,775	624,877	(1.3)%
Commercial		163,992		164,024	(0.0)%	1,394,272	1,382,151	0.9 %
Industrial		15,141		15,283	(0.9)%	186,085	189,882	(2.0)%
Other-retail/municipal		28,543		30,322	(5.9)%	314,338	326,717	(3.8)%
Total retail		310,374		313,649	(1.0)%	2,511,470	2,523,627	(0.5)%
Sales to the market		2,239		682	228.3 %	62,538	22,052	183.6 %
Adjustments to revenues		(4,195)		(4,155)	(1.0)%	-	-	-  %
Total	$	308,418	$	310,176	(0.6)%	2,574,008	2,545,679	1.1 %
Cooling degree days (normal 659)						620	707	(12.3)%

Electric operating revenues decreased $1.8 million or 0.6% for the nine months ended September 30, 2014, compared to the same period in 2013, due to the following:

(In millions)
Volume	$	(1.5)
Other		(1.8)
Sales to the market		1.5
Total	$	(1.8)

In July 2013, the PSCW authorized MGE to freeze 2014 rates at 2013 levels for retail electric customers.

·

Volume. During the nine months ended September 30, 2014, there was a 0.5% decrease in total retail sales volumes compared to the same period in the prior year driven by cooler than normal weather.

·

Other. During the nine months ended September 30, 2014, other items affecting electric operating revenues decreased $1.8 million primarily attributable to a decrease in demand charges and lower monthly on-peak sales.

·

Sales to the market. Sales to the market represent wholesale sales made to third parties who are not ultimate users of the electricity. These sales may include spot market transactions on the markets operated by MISO and PJM. These sales may also include bilateral sales to other utilities or power marketers. Generating units are dispatched by MISO based on cost considerations as well as reliability of the system. Sales to the market typically occur when MGE has more generation and purchases online than are needed for its own system demand. The excess electricity is then sold to others in the market. For the nine months ended September 30, 2014, market volumes increased compared to the same period in the prior year, reflecting increased opportunities for sales. In addition, market settlement resulted in higher revenue per kWh for the nine months ended September 30, 2014, reflecting higher market prices.

Electric fuel and purchased power

Electric fuel and purchased power costs reflect a decrease in internal generation volumes offset by an increase in the volume of purchased power when compared to the prior period. Adjustments related to the regulatory recovery for fuel costs, known as fuel rules, moderated the effects of that increased volume. These items are explained below.

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Fuel for electric generation

The expense for fuel for internal electric generation increased $1.3 million during the nine months ended September 30, 2014, compared to the same period in the prior year, due to the following:

(In millions)
Increase in per-unit cost	$	4.0
Decrease in volume		(2.7)
Total	$	1.3

This increase in expense reflects an 11.5% increase in per-unit cost of internal electric generation, partially offset by a 6.9% decrease in internal generated volume delivered to the system primarily as a result of reduced generation at Columbia to reduce coal use in order to maintain inventory levels.

Purchased power

Purchased power expense decreased $2.5 million during the nine months ended September 30, 2014, compared to the same period in the prior year, due to the following:

(In millions)
Increase in volume	$	8.0
Decrease in per-unit cost		(1.3)
Fuel Rules Adjustments
Decrease in recorded fuel rule surplus credit		(4.4)
Amortization of 2012 fuel rule surplus credits		(4.8)
Total	$	(2.5)

The decrease in expense reflects a 2.0% decrease in the per-unit cost of purchased power and a 14.0% increase in the volume of power purchased from third parties primarily as a result of the reduced generation at Columbia.

Under fuel rules, MGE is required to defer electric fuel-related costs that fall outside a 2% cost tolerance band around the amount used in the most recent rate proceeding. Any fuel rules adjustments are reflected in purchased power expense. Cost savings that may be returned to customers are recorded as an increase to purchased power expense, and higher costs that MGE is entitled to recover, after adjustment for excess revenues, are recorded as a reduction to purchased power expense. Any over/under recovery of the deferred costs is determined on an annual basis and adjusted in future billings to customers. During the nine months ended September 30, 2014, MGE amortized $4.8 million of the 2012 fuel rule surplus credits. No fuel-related cost savings were deferred during the current period, as compared to $4.4 million of cost savings (surplus credit) in the prior period.

Electric operating and maintenance expenses

Electric operating and maintenance expenses decreased $5.0 million during the nine months ended September 30, 2014, compared to the same period in 2013. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(4.7)
Decreased customer service costs		(0.6)
Decreased distribution expenses		(0.5)
Decreased customer accounts costs		(0.2)
Increased production expenses		0.8
Increased transmission costs		0.2
Total	$	(5.0)

For the nine months ended September 30, 2014, decreased administrative and general costs are primarily due to decreased pension and other postretirement benefit costs. Increased production expenses are primarily due to increased costs at Columbia.

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Gas Utility Operations - MGE Energy and MGE

Gas deliveries and revenues

The following table compares MGE's gas revenues and gas therms delivered by customer class during each of the periods indicated:

		Revenues				Therms Delivered
(In thousands, except HDD and average rate per therm of retail customer)		Nine Months Ended September 30,				Nine Months Ended September 30,
		2014		2013	% Change	2014	2013	% Change
Residential	$	84,275	$	66,034	27.6 %	76,626	67,181	14.1 %
Commercial/Industrial		76,460		52,758	44.9 %	103,313	89,836	15.0 %
Total retail		160,735		118,792	35.3 %	179,939	157,017	14.6 %
Gas transportation		2,223		2,181	1.9 %	27,651	27,048	2.2 %
Other revenues		377		400	(5.8)%	-	-	-  %
Total	$	163,335	$	121,373	34.6 %	207,590	184,065	12.8 %
Heating degree days (normal 4,512)						5,240	4,799	9.2 %
Average Rate Per Therm of
Retail Customer	$	0.893	$	0.757	18.0 %

Gas revenues increased $42.0 million or 34.6% for the nine months ended September 30, 2014, compared to the same period in 2013. These changes are related to the following factors:

(In millions)
Rate/PGA changes	$	24.6
Volume		17.4
Total	$	42.0

·

Rate/PGA changes. The average retail rate per therm for the nine months ended September 30, 2014, increased 18.0% compared to the same period in 2013, reflecting higher natural gas commodity costs. MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas.

·

Volume. For the nine months ended September 30, 2014, retail gas deliveries increased 14.6% compared to the same period in 2013, as a result of colder weather during the winter months compared to milder weather in the prior year.

Cost of gas sold

For the nine months ended September 30, 2014, cost of gas sold increased by $37.4 million, compared to the same period in the prior year. The cost per therm of natural gas increased 33.5%, which resulted in $27.0 million of increased expense. In addition, the volume of purchased gas increased 14.8%, which resulted in $10.4 million of increased expense.

Gas operating and maintenance expenses

Gas operating and maintenance expenses decreased by $1.6 million for the nine months ended September 30, 2014, compared to the same period in 2013. The following changes contributed to the net change:

(In millions)
Decreased administrative and general costs	$	(2.2)
Decreased customer service costs		(0.3)
Increased distribution expenses		0.5
Increased customer account costs		0.4
Total	$	(1.6)

For the nine months ended September 30, 2014, decreased administrative and general costs are primarily due to decreased pension and other postretirement benefit costs.

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Nonregulated Energy Operations - MGE Energy and MGE

For the nine months ended September 30, 2014 and 2013, net income at the nonregulated energy operations segment was $14.4 million and $15.5 million, respectively. The nonregulated energy operations are conducted through MGE Energy's subsidiaries: MGE Power Elm Road and MGE Power West Campus, which have been formed to construct, own and lease electric generating capacity to assist MGE.

Results reflect the recovery of force majeure costs associated with the construction of the Elm Road Units. In December 2012, as part of WEPCO's (the operator and primary owner of the Elm Road Units) 2013 Wisconsin rate case, the PSCW determined that 100% of the construction costs for the Elm Road Units were prudently incurred, and approved the recovery in rates of more than 99.5% of the force majeure costs. The recovery of the force majeure costs began in 2013, including a one-time cumulative adjustment pertaining to affected periods prior to the PSCW order. The portion pertaining to prior periods was fully reflected in 2013 results.

Transmission Investment Operations - MGE Energy and MGE

Transmission investment other income

For the nine months ended September 30, 2014 and 2013, other income at the transmission investment segment was $7.3 million and $7.0 million, respectively. The transmission investment segment holds our interest in ATC, and its income reflects our equity in the earnings of ATC. See Footnote 3 of Notes to Consolidated Financial Statements for additional information concerning ATC and summarized financial information regarding ATC.

Consolidated Income Taxes - MGE Energy and MGE

MGE Energy's and MGE's effective income tax rate for the nine months ended September 30, 2014 and 2013, was 37.8%.

Noncontrolling Interest, Net of Tax - MGE

The noncontrolling interest, net of tax, reflects the accounting required for MGE Energy's interest in MGE Power Elm Road (the Elm Road Units) and MGE Power West Campus (WCCF). MGE Energy owns 100% of MGE Power Elm Road and MGE Power West Campus; however, due to the contractual agreements for these projects with MGE, the entities are considered VIEs and their results are consolidated with those of MGE, the primary beneficiary of the VIEs. Also included in noncontrolling interest, net of tax, is MGE Energy's interest in MGE Transco, which holds our investment in ATC. The following table shows MGE Energy's noncontrolling interest, net of tax, reflected on MGE's consolidated statement of income:

		Nine Months Ended
		September 30,
(In millions)		2014		2013
MGE Power Elm Road	$	12.1	$	13.0
MGE Power West Campus		5.7		5.7
MGE Transco		2.0		1.8

Contractual Obligations and Commercial Commitments - MGE Energy and MGE

There were no material changes, other than from the normal course of business, to MGE Energy's and MGE's contractual obligations (representing cash obligations that are considered to be firm commitments) and commercial commitments (representing commitments triggered by future events) during the nine months ended September 30, 2014, except as noted below. Further discussion of the contractual obligations and commercial commitments is included in Footnote 8 of Notes to Consolidated Financial Statements in this Report, and Footnote 18 of Notes to Consolidated Financial Statements, and "Contractual Obligations and Commercial Commitments for MGE Energy and MGE" under "Management's Discussion and Analysis of Financial Condition and Results of Operations" in MGE Energy's and MGE's 2013 Annual Report on Form 10-K.

Purchase Contracts - MGE Energy and MGE

See Footnote 8.d. of Notes to Consolidated Financial Statements for a description of commitments at September 30, 2014 that MGE Energy and MGE have entered with respect to various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers.

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Liquidity and Capital Resources

Cash Flows

The following summarizes cash flows for MGE Energy and MGE during the nine months ended September 30, 2014 and 2013:

		MGE Energy				MGE
(In thousands)		2014		2013		2014		2013
Cash provided by/(used for):
Operating activities	$	120,972	$	108,600	$	122,747	$	107,826
Investing activities		(69,233)		(94,177)		(68,645)		(93,835)
Financing activities		(31,833)		14,550		(45,927)		22,249

Cash Provided by Operating Activities

MGE Energy

MGE Energy's consolidated net cash provided by operating activities is derived mainly from the electric and gas operations of its principal subsidiary, MGE.

Cash provided by operating activities for the nine months ended September 30, 2014, was $121.0 million, an increase of $12.4 million when compared to the same period in the prior year. The increase is primarily related to no pension contributions being made in 2014.

MGE Energy's net income increased $4.3 million for the nine months ended September 30, 2014, when compared to the same period in the prior year.

MGE Energy's federal and state taxes paid increased $12.3 million during the nine months ended September 30, 2014, when compared to the same period in the prior year, primarily due to federal tax payments made in 2014. No federal tax payments were made during the nine months ended September 30, 2013, due to the NOL as a result of bonus depreciation, which was fully utilized in 2013.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $2.3 million in cash provided by operating activities for the nine months ended September 30, 2014, primarily due to decreased unbilled revenues and decreased accounts receivable, partially offset by increased inventories and decreased other current liabilities. Working capital accounts (excluding prepaid and accrued taxes) resulted in $2.6 million in cash provided by operating activities for the nine months ended September 30, 2013, primarily due to decreased accounts receivable and decreased unbilled revenues, partially offset by decreased accounts payable and increased gas inventories.

A decrease in pension contribution resulted in an additional $31.5 million in cash provided by operating activities for the nine months ended September 30, 2014, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts. There have been no required contributions and no discretionary contributions for 2014.

A decrease in employee benefit plan expenses resulted in $9.9 million lower net cash provided by operations for the nine months ended September 30, 2014, when compared to the same period in the prior year

During the nine months ended September 30, 2013, MGE paid a make-whole premium equal to $6.8 million related to the redemption of $40 million of long-term debt.

MGE

Cash provided by operating activities for the nine months ended September 30, 2014, was $122.7 million, an increase of $14.9 million when compared to the same period in the prior year. The increase is primarily related to no pension contributions being made in 2014.

Net income increased $4.4 million for the nine months ended September 30, 2014, when compared to the same period in the prior year.

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MGE's federal and state taxes paid to MGE Energy increased $11.9 million during the nine months ended September 30, 2014, when compared to the same period in the prior year, primarily due to federal tax payments made in 2014. No federal tax payments were made during the nine months ended September 30, 2013, due to the NOL as a result of the bonus depreciation, which was fully utilized in 2013.

Working capital accounts (excluding prepaid and accrued taxes) resulted in $4.9 million in cash provided by operating activities for the nine months ended September 30, 2014, primarily due to decreased unbilled revenues and decreased accounts receivable, partially offset by increased inventories and decreased accounts payable. Working capital accounts (excluding prepaid taxes and accrued taxes) resulted in $3.0 million in cash provided by operating activities for the nine months ended September 30, 2013, primarily due to decreased accounts receivable, decreased unbilled revenues, and increased current liabilities, partially offset by decreased accounts payable and increased gas inventories.

A decrease in pension contribution resulted in an additional $31.5 million in cash provided by operating activities for the nine months ended September 30, 2014, when compared to the same period in the prior year. Pension contributions reflect amounts required by law and discretionary amounts. There have been no required contributions and no discretionary contributions for 2014.

A decrease in employee benefit plan expenses resulted in $9.9 million lower net cash provided by operations for the nine months ended September 30, 2014, when compared to the same period in the prior year

During the nine months ended September 30, 2013, MGE paid a make-whole premium equal to $6.8 million related to the redemption of $40 million of long-term debt.

Cash Used for Investing Activities

MGE Energy

MGE Energy's cash used for investing activities decreased $24.9 million for the nine months ended September 30, 2014, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2014, were $66.1 million. This amount represents a decrease of $26.0 million from the expenditures made in the same period in the prior year. This decrease primarily reflects $39.7 million of lower expenditures on the Columbia environmental project in 2014 versus 2013.

MGE

MGE's cash used for investing activities decreased $25.2 million for the nine months ended September 30, 2014, when compared to the same period in the prior year.

Capital expenditures for the nine months ended September 30, 2014, were $66.1 million. This amount represents a decrease of $26.0 million from the expenditures made in the same period in the prior year. This decrease primarily reflects $39.7 million of lower expenditures on the Columbia environmental project in 2014 versus 2013.

Cash Provided by (Used for) Financing Activities

MGE Energy

Cash used for MGE Energy's financing activities was $31.8 million for the nine months ended September 30, 2014, compared to $14.6 million of cash provided by MGE Energy's financing activities in the nine months ended September 30, 2013.

For the nine months ended September 30, 2014, dividends paid were $28.6 million compared to $27.7 million in the prior year. This increase was a result of a higher dividend per share ($0.826 vs. $0.799).

During the nine months ended September 30, 2013, MGE issued $85 million of long-term debt, which was used to retire $40 million of long-term debt and to assist with the funding for the Columbia environmental project.

MGE

During the nine months ended September 30, 2014, cash used for MGE's financing activities was $45.9 million compared to $22.2 million of cash provided by MGE's financing activities in the prior year.

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Dividends paid from MGE to MGE Energy were $26.5 million during the nine months ended September 30, 2014. There were no dividends paid from MGE to MGE Energy in 2013.

During the nine months ended September 30, 2013, MGE issued $85 million of long-term debt, which was used to retire $40 million of long-term debt and to assist with the funding for the Columbia environmental project.

Distributions to parent from noncontrolling interest, which represent distributions from MGE Power Elm Road and MGE Power West Campus, were $17.8 million for the nine months ended September 30, 2014, compared to $21.1 million in the prior year.

Capitalization Ratios

MGE Energy's capitalization ratios were as follows:

	MGE Energy
	September 30, 2014	December 31, 2013
Common shareholders' equity	62.0 %	60.5 %
Long-term debt*	38.0 %	39.5 %
*Includes the current portion of long-term debt.

MGE Energy's and MGE's Capital Requirements

MGE Energy's and MGE's liquidity are primarily affected by their capital requirements. During the nine months ended September 30, 2014, capital expenditures for MGE Energy and MGE totaled $66.1 million, which included $64.6 million of capital expenditures for utility operations.

In early 2011, the PSCW authorized the construction of air emission reduction systems and associated equipment on Columbia Units 1 and 2. For the nine months ended September 30, 2014, MGE had incurred $11.0 million (excluding carrying costs) in construction expenditures at Columbia related to the project and had accrued $5.0 million in incurred, but unpaid capital expenditures. MGE has recognized $3.0 million (after tax) in AFUDC equity related to this project for the nine months ended September 30, 2014.

Credit Ratings

MGE Energy's and MGE's access to the capital markets, including, in the case of MGE, the commercial paper market, and their respective financing costs in those markets, may depend on the credit ratings of the entity that is accessing the capital markets.

None of MGE Energy's or MGE's borrowing is subject to default or prepayment as a result of a downgrading of credit ratings, although a downgrading of MGE's credit ratings could increase fees and interest charges under both MGE Energy's and MGE's credit agreements.

Environmental Matters

The following discussion is limited to updates or developments in environmental matters that occurred during the nine months ended September 30, 2014. Further discussion of environmental matters is included in MGE Energy's and MGE's 2013 Annual Report on Form 10-K and Footnote 8.a. of Notes to Consolidated Financial Statements in this Report.

EPA's Final 316(b) Rule Governing Water Intake Systems at Electric Generating Facilities

In August 2014, the EPA published its Phase II and III Rules pursuant to Section 316(b) of the Clean Water Act, which governs cooling water intake structures located at large existing power plant and industrial facilities. The 316(b) Rule requires these facilities to implement methods for reducing fish impingement by their water intakes using one of seven options, including closed cycle cooling (CCC) systems.

Our WCCF facility already employs a CCC system as defined under the Rule. The Columbia plant may need to address multiple intake structures. Our Blount plant has conducted studies regarding compliance with this rule. The exact requirements at Blount and Columbia, however, will not be known until those sites' permits are modified to account for this rule. Nonetheless, MGE expects that this 316(b) Rule will not have material effects on its existing plants.

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EPA's Cross-State Air Pollution Rule (CSAPR) Upheld by the Supreme Court

On April 29, 2014, the US Supreme Court issued a decision upholding CSAPR, thereby reversing the D.C. Circuit Court's decision on CSAPR, and remanding the matter back to the D.C. Circuit for further proceedings. At that time CSAPR remained subject to an order of the D.C. Circuit that stayed its implementation. On October 23, 2014, the D.C. Circuit lifted its stay of CSAPR and set a briefing schedule for ongoing litigation with oral arguments scheduled for March 2015. The State of Wisconsin has filed a motion with the D.C. Circuit Court reiterating its contention that Wisconsin be removed from CSAPR and may be part of the court's briefing and oral arguments schedule. With several issues undecided and court proceedings extending into 2015, there is remaining uncertainty as to whether MGE's facilities will be required to meet the CSAPR mandates and, if so, the deadline for achieving compliance. The Clean Air Interstate Rule (CAIR) remains in effect for the time being. See MGE Energy's and MGE's 2013 Annual Report on Form 10K for additional information on the legal proceedings associated with these environmental matters.

With CSAPR now reinstated, it will require (once implemented) that qualifying power plants meet SO₂ and NO_x allocations or purchase them on the market. MGE has been monitoring our overall compliance options, particularly at our Columbia power plant as we awaited installation and testing of SO₂ controls. With the 2014 installation of SO₂ pollution controls at Columbia, we will likely meet or exceed the allocations for Columbia based on the CSAPR allocations in the current rule (see Footnote 4 for information regarding the Columbia environmental construction project and Footnote 8.a. for information regarding our consent decree). MGE expects that the costs pertaining to meeting CSAPR requirements will be fully recoverable through rates. We will continue to monitor and evaluate the D.C. Circuit Court remand proceedings and the implementation of the rule by the EPA and WDNR.

EPA's Greenhouse Gas Reduction Guidelines under the Clean Air Act 111d Rule

On June 2, 2014, the EPA released proposed guidelines for states to use in developing plans to control GHG emissions from existing fossil fuel fired electric generating units (EGUs). The proposed rule was published in the Federal Register on June 17, 2014.

The EPA's proposal seeks to reduce GHG emissions from EGUs by a national average of 30% by 2030 as measured from a 2005 baseline. Each state is given its own emission reduction targets to meet this goal. These targets are expressed as a "rate-based" emission average to be achieved by the combined fleet of EGUs within the state. States would be expected to make "meaningful progress" towards these reductions by 2020 and to meet their respective targets by 2030.

The EPA's proposal establishes guidelines for states and encourages the use of four "building blocks" for achieving these reductions. These "building blocks" are: (1) increasing the efficiency of EGUs; (2) re-dispatching of gas-fired generation at the expense of coal; (3) expanding the use of low and no carbon power sources, such as wind, nuclear and solar; and (4) improving demand side energy efficiency to reduce electric use.

The EPA is taking comments on the proposed rule through December 1, 2014. The rule is expected to be finalized by June 2015. States will then have up to two years to prepare compliance plans. This rule could have significant impacts on EGUs. MGE is reviewing the proposal at this time.

Coal Combustion Residual Rule

The EPA's proposed Coal Combustion Residual (CCR) is anticipated to be finalized in December 2014. The final CCR Rule will regulate disposal and management of ash and other coal combustion byproducts as a waste under the EPA's solid waste rules.

Columbia

Columbia is a coal-fired generating station operated by WPL in which WPL, WPSC, and MGE have ownership interests. In December 2009, the EPA sent a Notice of Violation (NOV) to MGE as one of the co-owners of Columbia. The NOV alleged that WPL and the Columbia co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the Prevention of Significant Deterioration program requirements, Title V Operating Permit requirements of the CAA, and the Wisconsin SIP. In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, the Sierra Club filed civil lawsuits against WPL alleging violations of the CAA at Columbia and other Wisconsin facilities operated by WPL. In June 2013, the court approved and entered a consent decree entered by the EPA, Sierra Club, and the co-owners of Columbia to resolve these claims, while admitting no liability. One of the requirements of the consent decree requires installation of a SCR system at Columbia Unit 2 by December 31, 2018. In July 2014, a CA was filed with the PSCW for the installation of the SCR system. MGE's share of the projected cost for the SCR system is approximately $30-40 million. See Footnote 8.a. of the Notes to Consolidated Financial Statements for additional information regarding this matter.

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Other Matters

Elm Road

The warranty periods for both of the Elm Road Units have expired. During 2013, WEPCO and Bechtel (the construction contractor for the Elm Road Units) were working through the outstanding warranty claims. The warranty claim for the costs incurred to repair steam turbine corrosion damage identified on both units was resolved through a binding arbitration in June 2013. Final acceptance of the Elm Road Units occurred in June 2013 after all requirements stated in the contract with Bechtel were satisfied. In April 2014, an additional warranty claim was resolved that did not have a material impact on our financial statements. The parties continue to work through one potential remaining warranty claim.

ATC

On November 12, 2013, MISO and numerous other MISO transmission owners, including ATC, were named as respondents in a complaint filed at FERC. The complainants argue that the respondents' transmission rates are no longer just and reasonable "due to changes in the capital markets," and that the MISO base return on equity (ROE) should not exceed 9.15%, equity components of hypothetical capital structures should be restricted to 50%, and that relevant incentive ROE adders should be discontinued. MISO's base ROE is 12.38% and ATC's base ROE is 12.2%. MISO and the other MISO transmission owners filed a motion to dismiss the complaint. MGE Energy and MGE are currently unable to determine what, if any, impact the complaint may have on MISO's and ATC's current authorized return on equity.

Joint Venture

MGE Energy has entered into a joint venture with Wisconsin Energy Corporation to evaluate the advisability and feasibility of potentially bidding on generating assets owned by the State of Wisconsin, which might include the University of Wisconsin's interest in the WCCF, which the Company co-owns and operates.

Should the State determine that the assets be sold, the joint venture would decide on a case-by-case basis whether to submit a bid. If the bid is successful, the joint venture would finance the acquisition and would own and manage the acquired assets. If those acquired assets include the State's interest in the WCCF, MGE would continue to operate the WCCF as it does currently.

New Accounting Principles

See Footnote 12 of Notes to Consolidated Financial Statements for discussion of new accounting pronouncements.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

MGE Energy and MGE are potentially exposed to market risk associated with interest rates, commodity prices, and equity returns. MGE currently has no exposure to foreign currency risk. MGE manages some risk exposure through risk management policies and the use of derivative instruments. MGE's risk management policy prohibits speculative trading transactions.

Commodity Price Risk

MGE has commodity price risk exposure with respect to the price of natural gas, electricity, coal, emission credits, and oil. MGE's electric operations burn natural gas in several of its peaking power plants and, in many cases, the cost of purchased power is tied to the cost of natural gas. MGE employs established policies and procedures to reduce the market risks associated with changing commodity prices. MGE's commodity risks are somewhat mitigated by the current ratemaking process in place for recovering electric fuel cost, purchased energy costs, and the cost of natural gas.

MGE's electric fuel costs are subject to fuel rules established by the PSCW. The fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band. Any over/under recovery of the actual costs is determined on an annual basis and is adjusted in future billings to electric retail customers. Under the electric fuel rules, MGE is required to defer the benefit of lower costs if the actual electric fuel costs fall outside the lower end of the range and is required to defer costs, less any excess revenues, if the actual electric fuel costs exceed the upper end of the range. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. The range is defined by the PSCW and has been modified throughout the years based on market conditions and other relevant factors. Currently, MGE is subject to a plus or minus 2% range. MGE assumes the risks and benefits of variances that are within the cost tolerance band. For 2014, fuel and purchased power costs included in MGE's base fuel rates are $106.1 million. See Footnote 10.b. of the Notes to Consolidated Financial Statements for additional information.

MGE recovers the cost of natural gas in its gas segment through the purchased gas adjustment clause (PGA). Under the PGA, MGE is able to pass through to its gas customers the cost of gas.

MGE also reduces price risk caused by market fluctuations via physical contracts and financial derivative contracts, including futures, swaps, options, forwards, and other contractual commitments. The maximum length of time over which cash flows related to energy commodities can be hedged under applicable PSCW approvals is four years.

MGE has financial gas and electric commodity contracts to hedge commodity price risk in the gas and electric segments. These contracts are primarily comprised of exchange-traded option and future contracts. MGE also holds FTRs, which are used to hedge the risk of increased transmission congestion charges. At September 30, 2014, the fair value of these instruments exceeded their cost basis by $2.3 million. Under the PGA clause and electric fuel rules, MGE may include in the costs of fuel (natural gas or power) the costs and benefits of the aforementioned fuel price risk management tools. Because these costs/benefits are recoverable, the related unrealized loss/gain has been deferred on the consolidated balance sheet as a regulatory asset/liability.

MGE has also entered into a ten-year purchased power agreement that provides MGE with firm capacity and energy that began on June 1, 2012, and ends on May 31, 2022 (the "base term"). The agreement also allows MGE an option to extend the contract after the base term. The agreement is considered a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at September 30, 2014, reflects a loss position of $54.9 million.

Interest Rate Risk

Both MGE Energy and MGE may have short term borrowings at varying interest rates. MGE issues commercial paper for its short-term borrowings, while MGE Energy draws from its current credit facility to meet its short-term borrowing needs. Borrowing levels vary from period to period depending upon capital investments and other factors. Future short-term interest expense and payments will reflect both future short-term interest rates and borrowing levels. MGE Energy and MGE manage interest rate risk by limiting their variable rate exposure and continually monitoring the effects of market changes on interest rates. MGE is not exposed to changes in interest rates on a substantial portion of its long-term debt until that debt matures and is refinanced at market rates.

48

Equity Price Risk - Pension-Related Assets

MGE currently funds its liabilities related to employee benefits through trust funds. These funds, which include investments in debt and equity securities, are managed by various investment managers. Changes in market value of these investments can have an impact on the future expenses related to these liabilities.

Credit Risk - Counterparty

Credit risk is the loss that may result from counterparty nonperformance. MGE is exposed to credit risk primarily through its merchant energy business. MGE uses credit policies to manage its credit risk, which include utilizing an established credit approval process, monitoring counterparty limits, employing credit mitigation measures such as collateral or prepayment arrangements, and using netting agreements.

Due to the possibility of extreme volatility in the prices of energy commodities and derivatives, the market value of contractual positions with individual counterparties could exceed established credit limits or collateral provided by those counterparties. If such a counterparty were then to fail to perform its obligations under its contract (for example, fail to deliver the electricity MGE originally contracted for), MGE could sustain a loss that could have a material impact on its financial results.

Additionally, if a counterparty were to default and MGE were to liquidate all contracts with that entity, MGE's credit loss would include the loss in value of mark-to-market contracts; the amount owed for settled transactions; and additional payments, if any, to settle unrealized losses on accrual contracts. As of September 30, 2014, no counterparties have defaulted.

MGE is obligated to provide service to all electric and gas customers within its respective franchised territories. MGE's franchised electric territory includes a 316 square-mile area in Dane County, Wisconsin, and MGE's franchised gas territory includes a service area covering 1,649 square miles in Wisconsin. Based on results for the year ended December 31, 2013, no one customer constituted more than 10% of total operating revenues for MGE Energy and MGE. Credit risk for electric and gas is managed by MGE's credit and collection policies, which are consistent with state regulatory requirements.

Cash, cash equivalents, and customer accounts receivable are the financial instruments that potentially subject MGE Energy and MGE to concentrations of credit risk. MGE Energy and MGE place their cash and cash equivalents with high credit-quality financial institutions. MGE has limited concentrations of credit risk from customer accounts receivable because of the large number of customers and relatively strong economy in its service territory.

49

Item 4. Controls and Procedures.

During the third quarter of 2014, each registrant's management, including the principal executive officer and principal financial officer, evaluated its disclosure controls and procedures related to the recording, processing, summarization, and reporting of information in its periodic reports that it files with the SEC. These disclosure controls and procedures have been designed to ensure that material information relating to that registrant, including its subsidiaries, is accumulated and made known to that registrant's management, including these officers, by other employees of that registrant and its subsidiaries as appropriate to allow timely decisions regarding required disclosure, and that this information is recorded, processed, summarized, evaluated, and reported, as applicable, within the time periods specified in the SEC's rules and forms. Due to the inherent limitations of control systems, not all misstatements may be detected. These inherent limitations include the realities that judgments in decision making can be faulty and breakdowns can occur because of simple error or mistake. Additionally, controls can be circumvented by the individual acts of some persons, by collusion of two or more people, or by management override of the control. Also, the registrants do not control or manage certain of their unconsolidated entities and thus, their access and ability to apply their procedures to those entities is more limited than is the case for their consolidated subsidiaries.

As of September 30, 2014, each registrant's principal executive officer and principal financial officer concluded that its disclosure controls and procedures were effective. Each registrant intends to strive continually to improve its disclosure controls and procedures to enhance the quality of its financial reporting.

During the quarter ended September 30, 2014, there were no changes in either registrant's internal controls over financial reporting that materially affected, or are reasonably likely to affect materially, that registrant's internal control over financial reporting.

50

PART II. OTHER INFORMATION.

Item 1. Legal Proceedings.

MGE Energy and MGE

MGE Energy and its subsidiaries, including MGE, from time to time are involved in various legal proceedings that are handled and defended in the ordinary course of business.

See Footnote 8.a. and 8.c. of Notes to Consolidated Financial Statements for more information.

Item 1A. Risk Factors.

There have been no material changes in the risk factors affecting MGE Energy and MGE from those factors discussed in in their 2013 Annual Report on Form 10-K, except as follows:

Our ability to obtain an adequate supply of coal could limit our ability to operate our coal-fired facilities.

The availability of coal and the means to transport coal could:

·

affect our operating costs due to increased costs associated with lower levels of generation or the need for alternate supply or alternate transportation,

·

limit our ability to generate electricity if we are unable to arrange adequate deliveries of coal, and

·

result in potentially higher costs for replacement purchased power as well as potential lost market sales opportunities.

A significant portion of our electric generating capacity is dependent on coal. Increased oil exploration and production in the United States has increased the amount of oil being transported by railroad, which has affected the availability and scheduling of trains to transport coal. Demand for coal has also been impacted by prevailing prices for natural gas and may affect mine performance. Consequently, we are exposed to the risk that counterparties to these contracts will not be able to fulfill their obligations. Disruption in the delivery of fuel, including disruptions as a result of transportation delays, weather, labor relations, force majeure events, or environmental regulations affecting any of these fuel suppliers, could limit our ability to generate electricity at our facilities at the desired level. Should counterparties fail to perform, or other unplanned disruptions occur, we may be forced to replace the underlying commitment at higher prices, or we may be forced to reduce generation at our coal units and replace this lost generation through additional power purchases from third parties. These factors may also affect the terms under which any of our existing coal supply or transportation agreements are renewed or replaced upon the expiration of their current terms.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

Issuer Purchases of Equity Securities

Period	Total Number of Shares Purchased		Average Price Paid per Share	Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs*	Maximum number (or Approximate Dollar Value) of Shares That May Yet Be Purchased Under the Plans or Programs*
July 1-31, 2014	33,010	$	39.34	-	-
August 1-31, 2014	27,821		39.19	-	-
September 1-30, 2014	78,425		39.61	-	-
Total	139,256	$	39.46	-	-

* Under the Stock Plan, common stock shares deliverable to plan participants may be either newly issued shares or shares purchased on the open market, as determined from time to time by MGE Energy. In June 2009, MGE Energy switched to using open market purchases to provide shares to meet obligations to participants in the Stock Plan. The shares are purchased on the open market through a securities broker-dealer and then are reissued under the Stock Plan as needed to meet share delivery requirements. The volume and timing of share repurchases in the open market depends upon the level of dividend reinvestment and optional share purchases being made from time to time by plan participants. As a result, there is no specified maximum number of shares to be repurchased and no specified termination date for the repurchases. All shares issued through the Stock Plan, whether newly issued or reissued following open market purchases, are issued and sold pursuant to a registration statement that was filed with the SEC and is currently effective.

51

Item 4. Mine Safety Disclosures.

Not applicable to MGE Energy and MGE.

Item 6. Exhibits.

12

Statement regarding computation of ratio of earnings to fixed charges for Madison Gas and Electric Company.

Certifications Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities and Exchange Act of 1934 as to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2014, filed by the following officers for the following companies:

31.1

Filed by Gary J. Wolter for MGE Energy, Inc.

31.2

Filed by Jeffrey C. Newman for MGE Energy, Inc.

31.3

Filed by Gary J. Wolter for Madison Gas and Electric Company

31.4

Filed by Jeffrey C. Newman for Madison Gas and Electric Company

Certifications Pursuant to Section 1350 of Chapter 63 of Title 18 United States Code (Sarbanes-Oxley Act of 2002) as to the Quarterly Report on Form 10-Q for the quarter ended September 30, 2014, filed by the following officers for the following companies:

32.1

Filed by Gary J. Wolter for MGE Energy, Inc.

32.2

Filed by Jeffrey C. Newman for MGE Energy, Inc.

32.3

Filed by Gary J. Wolter for Madison Gas and Electric Company

32.4

Filed by Jeffrey C. Newman for Madison Gas and Electric Company

101

Interactive Data Files:

101.INS

XBRL Instance

101.SCH

XBRL Taxonomy Extension Schema

101.CAL

XBRL Taxonomy Extension Calculation

101.DEF

XBRL Taxonomy Extension Definition

101.LAB

XBRL Taxonomy Extension Labels

101.PRE

XBRL Taxonomy Extension Presentation

52

Signatures - MGE Energy, Inc.

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	MGE ENERGY, INC.
Date: November 6, 2014	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 6, 2014	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

53

Signatures - Madison Gas and Electric Company

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.

	MADISON GAS AND ELECTRIC COMPANY
Date: November 6, 2014	/s/ Gary J. Wolter
	Gary J. Wolter Chairman, President and Chief Executive Officer (Duly Authorized Officer)
Date: November 6, 2014	/s/ Jeffrey C. Newman
	Jeffrey C. Newman Vice President, Chief Financial Officer, Secretary and Treasurer (Chief Financial and Accounting Officer)

54

EX-12

EXHIBIT 12

Madison Gas and Electric Company

Ratio of Earnings to Fixed Charges

Nine Months Ended September 30, 2014

(In thousands)

Earnings
Net income before minority interest	$65,255
Equity earnings	(7,306)
Income distribution from equity investees	5,762
Minority interest in pretax income	(3,300)
Amortization of capitalized interest	396
Federal and state income taxes	39,570
Fixed charges	16,433
Total Earnings as Defined	$116,810
Fixed Charges
Interest expense on long-term debt and other	$14,151
Interest on rentals*	667
Amortization of debt issuance costs	525
AFUDC - borrowed funds	1,090
Total Fixed Charges	$16,433
Ratio of Earnings to Fixed Charges	7.11X

*Management believes that using one-third of the total rental expense

gives a reasonable approximation for actual interest on rentals.

EX-31

EXHIBIT 31.1

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Gary J. Wolter, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of MGE Energy, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 6, 2014

EX-31

EXHIBIT 31.2

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Jeffrey C. Newman, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of MGE Energy, Inc.;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2014

EX-31

EXHIBIT 31.3

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Gary J. Wolter, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Madison Gas and Electric Company;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 6, 2014

EX-31

EXHIBIT 31.4

Certification Pursuant to Rule 13a-14(a) and 15d-14(a) of the Securities Exchange Act of 1934

I, Jeffrey C. Newman, certify that:

1.

I have reviewed this quarterly report on Form 10-Q of Madison Gas and Electric Company;

2.

Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.

Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.

The registrant's other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)

Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)

Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)

Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)

Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and

5.

The registrant's other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):

(a)

All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and

(b)

Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2014

EX-32

EXHIBIT 32.1

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended September 30, 2014, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Gary J. Wolter, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 6, 2014

EX-32

EXHIBIT 32.2

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of MGE Energy, Inc. (the "Company"), for the period ended September 30, 2014, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2014

EX-32

EXHIBIT 32.3

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended September 30, 2014, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Gary J. Wolter, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Gary J. Wolter

Gary J. Wolter

Chairman, President and Chief Executive Officer

Date: November 6, 2014

EX-32

EXHIBIT 32.4

Certification Pursuant to 18 U.S.C. Section 1350,

as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002

In connection with the quarterly report on Form 10-Q of Madison Gas and Electric Company (the "Company"), for the period ended September 30, 2014, as filed with the Securities and Exchange Commission on the date hereof ("the Report"), I, Jeffrey C. Newman, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1.

The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

2.

The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

/s/ Jeffrey C. Newman

Jeffrey C. Newman

Vice President, Chief Financial Officer,

Secretary and Treasurer

Date: November 6, 2014

XML

Pension and Other Postretirement Plans (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Pension Benefits [Member]
Components of net periodic (benefit) cost:
Service cost	$ 1,536	$ 1,924	$ 4,609	$ 5,764
Interest cost	3,367	3,178	10,102	9,521
Expected return on assets	(5,467)	(4,764)	(16,402)	(14,273)
Amortization of:
Prior service (benefit) cost	51	79	152	237
Actuarial loss	180	2,011	539	6,023
Net periodic (benefit) cost	(333)	2,428	(1,000)	7,272
Postretirement Benefits [Member]
Components of net periodic (benefit) cost:
Service cost	241	594	722	1,781
Interest cost	564	966	1,691	2,898
Expected return on assets	(478)	(542)	(1,432)	(1,626)
Amortization of:
Transition obligation	1	0	2	2
Prior service (benefit) cost	(487)	28	(1,462)	83
Actuarial loss	28	310	86	930
Net periodic (benefit) cost	$ (131)	$ 1,356	$ (393)	$ 4,068

XML

New Accounting Pronouncements (Details-1) (Accounting Standards Update 2014-11 - Repurchase-to-Maturity Transactions [Member], USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014
Accounting Standards Update 2014-11 - Repurchase-to-Maturity Transactions [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New accounting pronouncement, effect of adoption, increase in assets and liabilities (secured borrowings)	$ 4.0

XML

Derivative and Hedging Instruments (Details-5) (USD $)			3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended
	Sep. 30, 2014 counterparty	Dec. 31, 2013 counterparty	Sep. 30, 2014 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Commodity Derivative Contracts [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2014 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2014 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2014 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2014 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Financial Transmission Rights [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2014 Purchased Power Agreement [Member]	Sep. 30, 2014 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2014 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Fuel For Electric Generation Purchased Power [Member]	Sep. 30, 2014 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2014 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]	Sep. 30, 2013 Purchased Power Agreement [Member] Cost Of Gas Sold Expense [Member]
Realized losses (gains) on income statement [Line Items]
Realized losses (gains) on income statement			$ 480,000	$ (7,000)	$ (5,376,000)	$ (523,000)	$ (18,000)	$ 0	$ (1,367,000)	$ 608,000	$ (97,000)	$ (387,000)	$ (929,000)	$ (896,000)	$ 0	$ 0	$ 0	$ 0		$ 1,068,000	$ 1,126,000	$ 461,000	$ 3,479,000	$ 0	$ 0	$ 0	$ 0
Derivative collateral required to be posted for ten-year PPA [Abstract]
Minimum collateral that may be required to be posted																			20,000,000
Maximum collateral that may be required to be posted																			40,000,000
Collateral posted																			0
Counterparties in net liability position or default [Abstract]
Derivative, net liability position of counterparties (less than $0.1 million)	$ 100,000
Counterparties in net liability position		0
Number of counterparties in default	0

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Segment Information (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended				12 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013		Dec. 31, 2013
Segment Reporting Information [Line Items]
Operating revenues	$ 135,135		$ 140,099		$ 474,145		$ 435,624
Depreciation and amortization	(10,376)		(9,710)		(30,191)		(28,864)
Other operating expenses	(84,639)		(90,489)		(335,422)		(304,735)
Operating Income	40,120		39,900		108,532		102,025
Other income (deductions), net	2,636		3,750		10,736		9,770
Interest (expense) income, net	(5,141)		(4,605)		(14,550)		(13,937)
Income before income taxes	37,615		39,045		104,718		97,858
Income tax (provision) benefit	(14,286)		(14,692)		(39,585)		(37,030)
Net Income (Loss)	23,329		24,353		65,133		60,828
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,619,896				1,619,896				1,579,060
Capital expenditures					66,138		92,092		119,047
Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	112,869		119,836		308,418		310,176
Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	21,404		18,864		163,335		121,373
Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	862		1,399		2,392		4,075
Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	135,135		140,099		474,145		435,624
Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	113,025		120,008		308,819		310,586
Depreciation and amortization	(6,931)		(6,425)		(19,909)		(19,139)
Other operating expenses	(74,573)		(82,414)		(229,286)		(235,390)
Operating Income	31,521		31,169		59,624		56,057
Other income (deductions), net	136		1,166		2,999		2,226
Interest (expense) income, net	(2,832)		(2,309)		(7,571)		(7,028)
Income before income taxes	28,825		30,026		55,052		51,255
Income tax (provision) benefit	(10,758)		(11,021)		(19,602)		(18,148)
Net Income (Loss)	18,067		19,005		35,450		33,107
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	914,839				914,839				899,257
Capital expenditures					50,033				100,146
Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	23,018		21,621		170,465		131,822
Depreciation and amortization	(1,575)		(1,497)		(4,700)		(4,357)
Other operating expenses	(22,199)		(21,485)		(144,907)		(111,494)
Operating Income	(756)		(1,361)		20,858		15,971
Other income (deductions), net	8		92		(44)		69
Interest (expense) income, net	(808)		(729)		(2,429)		(2,166)
Income before income taxes	(1,556)		(1,998)		18,385		13,874
Income tax (provision) benefit	651		751		(7,378)		(5,844)
Net Income (Loss)	(905)		(1,247)		11,007		8,030
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	263,688				263,688				265,694
Capital expenditures					14,599				15,554
Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	11,536		12,059		34,409		35,999
Depreciation and amortization	(1,858)		(1,788)		(5,547)		(5,368)
Other operating expenses	(35)		(33)		(105)		(96)
Operating Income	9,643		10,238		28,757		30,535
Other income (deductions), net	0		0		0		0
Interest (expense) income, net	(1,545)		(1,596)		(4,676)		(4,814)
Income before income taxes	8,098		8,642		24,081		25,721
Income tax (provision) benefit	(3,251)		(3,469)		(9,665)		(10,209)
Net Income (Loss)	4,847		5,173		14,416		15,512
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	307,599				307,599				288,116
Capital expenditures					1,506				3,347
Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
Depreciation and amortization	0		0		0		0
Other operating expenses	0		(1)		0		(1)
Operating Income	0		(1)		0		(1)
Other income (deductions), net	2,423		2,340		7,306		7,045
Interest (expense) income, net	0		0		0		0
Income before income taxes	2,423		2,339		7,306		7,044
Income tax (provision) benefit	(963)		(939)		(2,924)		(2,837)
Net Income (Loss)	1,460		1,400		4,382		4,207
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	67,476				67,476				64,504
Capital expenditures					0				0
Operating Segments [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
Depreciation and amortization	(12)		0		(35)		0
Other operating expenses	(276)		(145)		(672)		(537)
Operating Income	(288)		(145)		(707)		(537)
Other income (deductions), net	69		152		475		430
Interest (expense) income, net	44		29		126		71
Income before income taxes	(175)		36		(106)		(36)
Income tax (provision) benefit	35		(14)		(16)		8
Net Income (Loss)	(140)		22		(122)		(28)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	443,898				443,898				431,436
Capital expenditures					0				0
Operating Segments [Member] | Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	30,962				30,962				19,853
Capital expenditures					0				0
Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(12,444)		(13,589)		(39,548)		(42,783)
Depreciation and amortization	0		0		0		0
Other operating expenses	12,444		13,589		39,548		42,783
Operating Income	0		0		0		0
Other income (deductions), net	0		0		0		0
Interest (expense) income, net	0		0		0		0
Income before income taxes	0		0		0		0
Income tax (provision) benefit	0		0		0		0
Net Income (Loss)	0		0		0		0
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(408,566)				(408,566)				(389,800)
Capital expenditures					0				0
Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	156		172		401		410
Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,614		2,757		7,130		10,449
Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,674		10,660		32,017		31,924
Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
Consolidation Elimination Entries [Member] | All Others [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
MGE [Member]
Segment Reporting Information [Line Items]
Operating revenues	135,147		140,099		474,178		435,624
Depreciation and amortization	(10,364)		(9,710)		(30,156)		(28,864)
Other operating expenses	(97,712)	[1]	(104,143)	[1]	(370,962)	[1]	(338,435)	[1]
Operating Income	27,071		26,246		73,060		68,325
Other income (deductions), net	1,583		2,719		6,871		6,539
Interest (expense) income, net	(5,185)		(4,634)		(14,676)		(14,008)
Income tax (provision) benefit	(13,338)		(13,798)		(36,180)		(34,237)
Net Income Including Noncontrolling Interest	23,469		24,331		65,255		60,856
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,653)		(6,861)		(19,784)		(20,547)
Net Income (Loss)	16,816		17,470		45,471		40,309
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	1,558,702				1,558,702				1,530,643
Capital expenditures					66,138		92,092		119,047
MGE [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	112,875		119,836		308,435		310,176
MGE [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	21,410		18,864		163,351		121,373
MGE [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	862		1,399		2,392		4,075
MGE [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
MGE [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Operating revenues	135,147		140,099		474,178		435,624
MGE [Member] | Operating Segments [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	113,025		120,008		308,819		310,586
Depreciation and amortization	(6,931)		(6,425)		(19,909)		(19,139)
Other operating expenses	(85,314)	[1]	(93,481)	[1]	(248,525)	[1]	(253,566)	[1]
Operating Income	20,780	[1]	20,102	[1]	40,385	[1]	37,881	[1]
Other income (deductions), net	119	[1]	1,212	[1]	2,636	[1]	2,254	[1]
Interest (expense) income, net	(2,832)		(2,309)		(7,571)		(7,028)
Net Income Including Noncontrolling Interest	18,067		19,005		35,450		33,107
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0		0		0
Net Income (Loss)	18,067		19,005		35,450		33,107
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	917,503				917,503				899,257
Capital expenditures					50,033				100,146
MGE [Member] | Operating Segments [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	23,018		21,621		170,465		131,822
Depreciation and amortization	(1,575)		(1,497)		(4,700)		(4,357)
Other operating expenses	(21,544)	[1]	(20,748)	[1]	(152,182)	[1]	(117,346)	[1]
Operating Income	(101)	[1]	(624)	[1]	13,583	[1]	10,119	[1]
Other income (deductions), net	4	[1]	106	[1]	(147)	[1]	77	[1]
Interest (expense) income, net	(808)		(729)		(2,429)		(2,166)
Net Income Including Noncontrolling Interest	(905)		(1,247)		11,007		8,030
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0		0		0
Net Income (Loss)	(905)		(1,247)		11,007		8,030
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	262,237				262,237				265,694
Capital expenditures					14,599				15,554
MGE [Member] | Operating Segments [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	11,536		12,059		34,409		35,999
Depreciation and amortization	(1,858)		(1,788)		(5,547)		(5,368)
Other operating expenses	(3,286)	[1]	(3,502)	[1]	(9,770)	[1]	(10,305)	[1]
Operating Income	6,392	[1]	6,769	[1]	19,092	[1]	20,326	[1]
Other income (deductions), net	0	[1]	0	[1]	0	[1]	0	[1]
Interest (expense) income, net	(1,545)		(1,596)		(4,676)		(4,814)
Net Income Including Noncontrolling Interest	4,847		5,173		14,416		15,512
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0		0		0
Net Income (Loss)	4,847		5,173		14,416		15,512
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	286,600				286,600				288,066
Capital expenditures					1,506				3,347
MGE [Member] | Operating Segments [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	0		0		0		0
Depreciation and amortization	0		0		0		0
Other operating expenses	0	[1]	(1)	[1]	0	[1]	(1)	[1]
Operating Income	0	[1]	(1)	[1]	0	[1]	(1)	[1]
Other income (deductions), net	1,460	[1]	1,401	[1]	4,382	[1]	4,208	[1]
Interest (expense) income, net	0		0		0		0
Net Income Including Noncontrolling Interest	1,460		1,400		4,382		4,207
Less Net Income Attributable to Noncontrolling Interest, net of tax	0		0		0		0
Net Income (Loss)	1,460		1,400		4,382		4,207
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	67,476				67,476				64,504
Capital expenditures					0				0
MGE [Member] | Operating Segments [Member] | Assets Not Allocated [Member]
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	30,778				30,778				19,853
Capital expenditures					0				0
MGE [Member] | Consolidation Elimination Entries [Member]
Segment Reporting Information [Line Items]
Operating revenues	(12,432)		(13,589)		(39,515)		(42,783)
Depreciation and amortization	0		0		0		0
Other operating expenses	12,432	[1]	13,589	[1]	39,515	[1]	42,783	[1]
Operating Income	0	[1]	0	[1]	0	[1]	0	[1]
Other income (deductions), net	0	[1]	0	[1]	0	[1]	0	[1]
Interest (expense) income, net	0		0		0		0
Net Income Including Noncontrolling Interest	0		0		0		0
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,653)		(6,861)		(19,784)		(20,547)
Net Income (Loss)	(6,653)		(6,861)		(19,784)		(20,547)
Segment Reporting Assets And Capital Expenditures [Abstract]
Assets	(5,892)				(5,892)				(6,731)
Capital expenditures					0				0
MGE [Member] | Consolidation Elimination Entries [Member] | Electric [Member]
Segment Reporting Information [Line Items]
Operating revenues	150		172		384		410
MGE [Member] | Consolidation Elimination Entries [Member] | Gas [Member]
Segment Reporting Information [Line Items]
Operating revenues	1,608		2,757		7,114		10,449
MGE [Member] | Consolidation Elimination Entries [Member] | Non Regulated Energy [Member]
Segment Reporting Information [Line Items]
Operating revenues	10,674		10,660		32,017		31,924
MGE [Member] | Consolidation Elimination Entries [Member] | Transmission Investment [Member]
Segment Reporting Information [Line Items]
Operating revenues	$ 0		$ 0		$ 0		$ 0

[1] *Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

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Derivative and Hedging Instruments (Details-3) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Commodity Derivative Contracts [Member]
Offsetting Liabilities [Line Items]
Gross amounts	$ 536	$ 99
Gross amounts offset in balance sheet	(525)	(99)
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	11	0
Purchased Power Agreement [Member]
Offsetting Liabilities [Line Items]
Gross amounts	54,940	65,680
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 54,940	$ 65,680

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Segment Information (Tables)

9 Months Ended

Sep. 30, 2014

Segment Reporting [Abstract]

Segment Information

The following tables show segment information for MGE Energy's operations for the indicated periods:

(In thousands)MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2014
Operating revenues	$	112,869	$	21,404	$	862	$	-	$	-	$	-	$	135,135
Interdepartmental revenues		156		1,614		10,674		-		-		(12,444)		-
Total operating revenues		113,025		23,018		11,536		-		-		(12,444)		135,135
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		(12)		-		(10,376)
Other operating expenses		(74,573)		(22,199)		(35)		-		(276)		12,444		(84,639)
Operating income (loss)		31,521		(756)		9,643		-		(288)		-		40,120
Other income, net		136		8		-		2,423		69		-		2,636
Interest (expense) income, net		(2,832)		(808)		(1,545)		-		44		-		(5,141)
Income (loss) before taxes		28,825		(1,556)		8,098		2,423		(175)		-		37,615
Income tax (provision) benefit		(10,758)		651		(3,251)		(963)		35		-		(14,286)
Net income (loss)	$	18,067	$	(905)	$	4,847	$	1,460	$	(140)	$	-	$	23,329
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		-		(9,710)
Other operating expenses		(82,414)		(21,485)		(33)		(1)		(145)		13,589		(90,489)
Operating income (loss)		31,169		(1,361)		10,238		(1)		(145)		-		39,900
Other income, net		1,166		92		-		2,340		152		-		3,750
Interest (expense) income, net		(2,309)		(729)		(1,596)		-		29		-		(4,605)
Income (loss) before taxes		30,026		(1,998)		8,642		2,339		36		-		39,045
Income tax (provision) benefit		(11,021)		751		(3,469)		(939)		(14)		-		(14,692)
Net income (loss)	$	19,005	$	(1,247)	$	5,173	$	1,400	$	22	$	-	$	24,353
Nine Months Ended September 30, 2014
Operating revenues	$	308,418	$	163,335	$	2,392	$	-	$	-	$	-	$	474,145
Interdepartmental revenues		401		7,130		32,017		-		-		(39,548)		-
Total operating revenues		308,819		170,465		34,409		-		-		(39,548)		474,145
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		(35)		-		(30,191)
Other operating expenses		(229,286)		(144,907)		(105)		-		(672)		39,548		(335,422)
Operating income (loss)		59,624		20,858		28,757		-		(707)		-		108,532
Other (deductions) income, net		2,999		(44)		-		7,306		475		-		10,736
Interest (expense) income, net		(7,571)		(2,429)		(4,676)		-		126		-		(14,550)
Income (loss) before taxes		55,052		18,385		24,081		7,306		(106)		-		104,718
Income tax provision		(19,602)		(7,378)		(9,665)		(2,924)		(16)		-		(39,585)
Net income (loss)	$	35,450	$	11,007	$	14,416	$	4,382	$	(122)	$	-	$	65,133
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		-		(28,864)
Other operating expenses		(235,390)		(111,494)		(96)		(1)		(537)		42,783		(304,735)
Operating income (loss)		56,057		15,971		30,535		(1)		(537)		-		102,025
Other income, net		2,226		69		-		7,045		430		-		9,770
Interest (expense) income, net		(7,028)		(2,166)		(4,814)		-		71		-		(13,937)
Income (loss) before taxes		51,255		13,874		25,721		7,044		(36)		-		97,858
Income tax (provision) benefit		(18,148)		(5,844)		(10,209)		(2,837)		8		-		(37,030)
Net income (loss)	$	33,107	$	8,030	$	15,512	$	4,207	$	(28)	$	-	$	60,828

The following tables show segment information for MGE's operations for the indicated periods:

(In thousands)MGE		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2014
Operating revenues	$	112,875	$	21,410	$	862	$	-	$	-	$	135,147
Interdepartmental revenues		150		1,608		10,674		-		(12,432)		-
Total operating revenues		113,025		23,018		11,536		-		(12,432)		135,147
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		-		(10,364)
Other operating expenses*		(85,314)		(21,544)		(3,286)		-		12,432		(97,712)
Operating income (loss)*		20,780		(101)		6,392		-		-		27,071
Other income, net*		119		4		-		1,460		-		1,583
Interest expense, net		(2,832)		(808)		(1,545)		-		-		(5,185)
Net income (loss)		18,067		(905)		4,847		1,460		-		23,469
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,653)		(6,653)
Net income (loss) attributable to MGE	$	18,067	$	(905)	$	4,847	$	1,460	$	(6,653)	$	16,816
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		(9,710)
Other operating expenses*		(93,481)		(20,748)		(3,502)		(1)		13,589		(104,143)
Operating income (loss)*		20,102		(624)		6,769		(1)		-		26,246
Other income, net*		1,212		106		-		1,401		-		2,719
Interest expense, net		(2,309)		(729)		(1,596)		-		-		(4,634)
Net income (loss)		19,005		(1,247)		5,173		1,400		-		24,331
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,861)		(6,861)
Net income (loss) attributable to MGE	$	19,005	$	(1,247)	$	5,173	$	1,400	$	(6,861)	$	17,470
Nine Months Ended September 30, 2014
Operating revenues	$	308,435	$	163,351	$	2,392	$	-	$	-	$	474,178
Interdepartmental revenues		384		7,114		32,017		-		(39,515)		-
Total operating revenues		308,819		170,465		34,409		-		(39,515)		474,178
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		-		(30,156)
Other operating expenses*		(248,525)		(152,182)		(9,770)		-		39,515		(370,962)
Operating income*		40,385		13,583		19,092		-		-		73,060
Other (deductions) income, net*		2,636		(147)		-		4,382		-		6,871
Interest expense, net		(7,571)		(2,429)		(4,676)		-		-		(14,676)
Net income		35,450		11,007		14,416		4,382		-		65,255
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,784)		(19,784)
Net income attributable to MGE	$	35,450	$	11,007	$	14,416	$	4,382	$	(19,784)	$	45,471
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		(28,864)
Other operating expenses*		(253,566)		(117,346)		(10,305)		(1)		42,783		(338,435)
Operating income (loss)*		37,881		10,119		20,326		(1)		-		68,325
Other income, net*		2,254		77		-		4,208		-		6,539
Interest expense, net		(7,028)		(2,166)		(4,814)		-		-		(14,008)
Net income		33,107		8,030		15,512		4,207		-		60,856
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(20,547)		(20,547)
Net income attributable to MGE	$	33,107	$	8,030	$	15,512	$	4,207	$	(20,547)	$	40,309
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:
		Utility						Consolidated
(In thousands)MGE Energy		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2014	$	914,839	$	263,688	$	30,962	$	307,599	$	67,476	$	443,898	$	(408,566)	$	1,619,896
December 31, 2013		899,257		265,694		19,853		288,116		64,504		431,436		(389,800)		1,579,060
Capital Expenditures:
Nine Months Ended September 30, 2014	$	50,033	$	14,599	$	-	$	1,506	$	-	$	-	$	-	$	66,138
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		-		119,047

		Utility						Consolidated
(In thousands)MGE		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Elimination Entries		Total
Assets:
September 30, 2014	$	917,503	$	262,237	$	30,778	$	286,600	$	67,476	$	(5,892)	$	1,558,702
December 31, 2013		899,257		265,694		19,853		288,066		64,504		(6,731)		1,530,643
Capital Expenditures:
Nine Months Ended September 30, 2014	$	50,033	$	14,599	$	-	$	1,506	$	-	$	-	$	66,138
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		119,047

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New Accounting Pronouncements

9 Months Ended

Sep. 30, 2014

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements

New Accounting Pronouncements - MGE Energy and MGE.

a.Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance became effective January 1, 2014. The authoritative guidance did not have a financial or disclosure impact.

b. Presentation of an Unrecognized Tax Benefit.

In July 2013, the FASB issued authoritative guidance within the Codification's Income Statement topic that provides guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The authoritative guidance was issued to eliminate diversity in practice by providing guidance on the presentation of unrecognized tax benefits. This authoritative guidance became effective January 1, 2014. The authoritative guidance will not have a financial statement or disclosure impact, unlessMGE Energy or its subsidiaries are in a net operating loss position. MGE Energy or its subsidiaries are currently not in a net operating loss position.

c.Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2017. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

d.Transfers and Servicing Assets.

In June 2014, the FASB issued authoritative guidance within the Codification's Transfers and Servicing topic that provides guidance on the accounting and disclosures for repurchase-to-maturity transactions, securities lending transactions, and repurchase financings. This authoritative guidance will become effective January 1, 2015. The authoritative guidance will change the accounting for the Chattel Paper program. Prior to adoption of the standard, Chattel Paper was treated as an off-balance sheet arrangement. Upon adoption, assets and liabilities will increase approximately $4.0 million and additional disclosures will be required. The cumulative impact of this guidance on our financial statements is not expected to be material.

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Fair Value of Financial Instruments (Details-1) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014		Dec. 31, 2013
Carrying Amount [Member]
Assets:
Cash and cash equivalents	$ 88,719		$ 68,813
Liabilities:
Long-term debt	400,724	[1]	403,793	[1]
Fair Value [Member]
Assets:
Cash and cash equivalents	88,719		68,813
Liabilities:
Long-term debt	443,203	[1]	432,010	[1]
MGE [Member] | Carrying Amount [Member]
Assets:
Cash and cash equivalents	22,983		14,808
Liabilities:
Long-term debt	400,724	[1]	403,793	[1]
MGE [Member] | Fair Value [Member]
Assets:
Cash and cash equivalents	22,983		14,808
Liabilities:
Long-term debt	$ 443,203	[1]	$ 432,010	[1]

[1] *Includes long-term debt due within one year.

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Commitments and Contingencies (Details-2) (Chattel Paper Agreement [Member], USD $)	9 Months Ended
	Sep. 30, 2014
Guarantor Obligations [Line Items]
Guarantor obligation, maximum financing receivable	$ 10,000,000
Guarantor obligation, current carrying value	4,100,000
Servicing asset recognized	200,000
Guarantor Obligation, Fiscal Year Maturity [Abstract]
Guarantor obligation, 2014	108,000
Guarantor obligation, 2015	921,000
Guarantor obligation, 2016	841,000
Guarantor obligation, 2017	438,000
Guarantor obligation, 2018	$ 374,000
Minimum [Member]
Guarantor Obligations [Line Items]
Guarantee to financial institution, term	1 year
Maximum [Member]
Guarantor Obligations [Line Items]
Guarantee to financial institution, term	10 years

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Columbia Environmental Project Construction (Details) (USD $)			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended			12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013	Sep. 30, 2014 MGE [Member]	Sep. 30, 2013 MGE [Member]	Sep. 30, 2014 MGE [Member]	Sep. 30, 2013 MGE [Member]	Dec. 31, 2013 MGE [Member]	Sep. 30, 2014 MGE [Member] Columbia Environmental Project [Member]	Sep. 30, 2013 MGE [Member] Columbia Environmental Project [Member]	Sep. 30, 2014 MGE [Member] Columbia Environmental Project [Member]	Sep. 30, 2013 MGE [Member] Columbia Environmental Project [Member]	Sep. 30, 2014 MGE [Member] Columbia Environmental Project [Member] PSCW [Member]	Dec. 31, 2013 MGE [Member] Columbia Environmental Project [Member] PSCW [Member]	Sep. 30, 2014 Columbia Units [Member] WPL [Member]	Sep. 30, 2014 Columbia Units [Member] WPSC [Member]	Sep. 30, 2014 Columbia Units [Member] MGE [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly owned utility plant, ownership interest														46.20%	31.80%	22.00%
Property, plant, and equipment, total	$ 1,176,592,000	$ 1,018,809,000	$ 1,175,695,000		$ 1,175,695,000		$ 1,017,877,000	$ 138,600,000		$ 138,600,000
Property, plant, and equipment, portion related to capital expenditures								128,800,000		128,800,000
Property, plant, and equipment, portion related to AFUDC								9,800,000		9,800,000
Contractual commitments								5,500,000		5,500,000
AFUDC - equity funds			$ 255,000	$ 852,000	$ 3,306,000	$ 2,178,000		$ 100,000	$ 800,000	$ 3,000,000	$ 1,900,000
Authorized AFUDC Rate												100.00%	50.00%
Authorized MGE rate of return													50.00%

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Fair Value of Financial Instruments (Details-3)	9 Months Ended	12 Months Ended
	Sep. 30, 2014	Dec. 31, 2013
Fair Value Inputs Assets Quantitative Information [Line Items]
Basis adjustment - on peak	97.50%	94.20%
Basis adjustment - off peak	94.40%	92.60%
US Treasury Bill Securities [Member]
Deferred compensation plan [Abstract]
Investment interest calculation, investment maturity period (26 weeks)	182 days
Investment interest calculation, monthly compounding rate	1.00%
Investment interest calculation, minimum annual rate compounded monthly	7.00%
Minimum [Member]
Counterparty fuel mix [Abstract]
Internal generation	50.00%	50.00%
Purchased power	50.00%	50.00%
Maximum [Member]
Counterparty fuel mix [Abstract]
Internal generation	70.00%	70.00%
Purchased power	30.00%	30.00%

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Derivative and Hedging Instruments (Details-4) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Regulatory Asset [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	$ 48,853	$ 66,649	$ 63,893	$ 72,329
Change in unrealized loss (gain)	5,329	2,330	(18,090)	(1,330)
Realized gain (loss) reclassified to a deferred account	(314)	(275)	1,120	(953)
Realized gain (loss) reclassified to income statement	(1,184)	(621)	5,761	(1,963)
Ending balance,	52,684	68,083	52,684	68,083
Other Current Assets [Member]
Change In Derivative Fair Value [Roll Forward]
Beginning balance,	676	658	411	574
Change in unrealized loss (gain)	0	0	0	0
Realized gain (loss) reclassified to a deferred account	314	275	(1,120)	953
Realized gain (loss) reclassified to income statement	(249)	(111)	1,450	(705)
Ending balance,	$ 741	$ 822	$ 741	$ 822

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Consolidated Balance Sheets (Unaudited) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Current Assets:
Cash and cash equivalents	$ 88,719	$ 68,813
Accounts receivable, less reserves	35,251	44,890
Other accounts receivables, less reserves	5,365	5,352
Unbilled revenues	19,929	31,982
Materials and supplies, at average cost	17,524	16,662
Fossil fuel	5,121	5,206
Stored natural gas, at average cost	23,292	13,988
Prepaid taxes	15,569	19,106
Regulatory assets - current	4,985	6,377
Other current assets	9,650	8,225
Total Current Assets	225,405	220,601
Regulatory assets	100,227	107,166
Pension benefits	17,942	15,071
Other deferred assets and other	7,029	8,046
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,176,592	1,018,809
Construction work in progress	21,331	141,415
Total Property, Plant, and Equipment	1,197,923	1,160,224
Investments	71,370	67,952
Total Assets	1,619,896	1,579,060
Current Liabilities:
Long-term debt due within one year	4,162	4,102
Accounts payable	41,871	43,684
Accrued interest and taxes	4,041	5,661
Accrued payroll related items	10,305	10,731
Deferred income taxes	0	1,711
Regulatory liabilities - current	8,822	13,538
Derivative liabilities	7,131	7,750
Other current liabilities	5,824	9,489
Total Current Liabilities	82,156	96,666
Other Credits:
Deferred income taxes	313,101	284,791
Investment tax credit - deferred	1,274	1,413
Regulatory liabilities	21,970	19,792
Accrued pension and other postretirement benefits	50,339	49,184
Derivative liabilities	47,820	57,930
Other deferred liabilities and other	52,947	52,360
Total Other Credits	487,451	465,470
Capitalization:
Common shareholders equity	653,985	617,510
Long-term debt	396,304	399,414
Total Capitalization	1,050,289	1,016,924
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	1,619,896	1,579,060
MGE [Member]
Current Assets:
Cash and cash equivalents	22,983	14,808
Accounts receivable, less reserves	35,251	44,890
Affiliate receivables	609	534
Other accounts receivables, less reserves	5,290	5,274
Unbilled revenues	19,929	31,982
Materials and supplies, at average cost	17,524	16,662
Fossil fuel	5,121	5,206
Stored natural gas, at average cost	23,292	13,988
Prepaid taxes	20,390	23,934
Regulatory assets - current	4,985	6,377
Other current assets	9,546	8,197
Total Current Assets	164,920	171,852
Affiliate receivable long-term	5,428	5,825
Regulatory assets	100,227	107,166
Pension benefits	17,942	15,071
Other deferred assets and other	4,987	6,138
Property, Plant, and Equipment:
Property, plant, and equipment, net	1,175,695	1,017,877
Construction work in progress	21,331	141,415
Total Property, Plant, and Equipment	1,197,026	1,159,292
Investments	68,172	65,299
Total Assets	1,558,702	1,530,643
Current Liabilities:
Long-term debt due within one year	4,162	4,102
Accounts payable	41,861	43,684
Accrued interest and taxes	3,774	6,040
Accrued payroll related items	10,305	10,731
Deferred income taxes	1,143	2,723
Regulatory liabilities - current	8,822	13,538
Derivative liabilities	7,131	7,750
Other current liabilities	5,495	6,446
Total Current Liabilities	82,693	95,014
Other Credits:
Deferred income taxes	306,559	279,085
Investment tax credit - deferred	1,274	1,413
Regulatory liabilities	21,970	19,792
Accrued pension and other postretirement benefits	50,338	49,184
Derivative liabilities	47,820	57,930
Other deferred liabilities and other	52,947	52,357
Total Other Credits	480,908	459,761
Capitalization:
Common shareholders equity	476,408	457,491
Noncontrolling interest	122,389	118,963
Total Equity	598,797	576,454
Long-term debt	396,304	399,414
Total Capitalization	995,101	975,868
Commitments and contingencies (see Footnote 8)
Total Liabilities and Capitalization	$ 1,558,702	$ 1,530,643

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Commitments and Contingencies (Details-3) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	$ 62,902
Purchase obligation, 2015	101,546
Purchase obligation, 2016	70,335
Purchase obligation, 2017	55,477
Purchase obligation, 2018	54,054
Coal [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	11,950	[1]
Purchase obligation, 2015	18,439	[1]
Purchase obligation, 2016	10,765	[1]
Purchase obligation, 2017	5,073	[1]
Purchase obligation, 2018	2,710	[1]
Natural Gas, Transportation and Storage [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	5,234	[2]
Purchase obligation, 2015	18,073	[2]
Purchase obligation, 2016	9,937	[2]
Purchase obligation, 2017	272	[2]
Purchase obligation, 2018	191	[2]
Natual Gas, Supply [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	16,951	[3]
Purchase obligation, 2015	16,070	[3]
Purchase obligation, 2016	0	[3]
Purchase obligation, 2017	0	[3]
Purchase obligation, 2018	0	[3]
Purchase Power [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	12,665	[4]
Purchase obligation, 2015	48,964	[4]
Purchase obligation, 2016	49,633	[4]
Purchase obligation, 2017	50,132	[4]
Purchase obligation, 2018	51,153	[4]
Other [Member]
Operating expense purchase contracts [Abstract]
Purchase obligation, 2014	16,102
Purchase obligation, 2015	0
Purchase obligation, 2016	0
Purchase obligation, 2017	0
Purchase obligation, 2018	$ 0

[1] Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurements for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, who are the operators of those facilities. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

[2] MGE’s natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

[3] These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

[4] MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates.

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Pension and Other Postretirement Plans (Tables)

9 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Schedule of Net Periodic Benefit Costs

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months endedSeptember 30,2014 and 2013. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,536	$	1,924	$	4,609	$	5,764
Interest cost		3,367		3,178		10,102		9,521
Expected return on assets		(5,467)		(4,764)		(16,402)		(14,273)
Amortization of:
Prior service cost		51		79		152		237
Actuarial loss		180		2,011		539		6,023
Net periodic (benefit) cost	$	(333)	$	2,428	$	(1,000)	$	7,272
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	241	$	594	$	722	$	1,781
Interest cost		564		966		1,691		2,898
Expected return on assets		(478)		(542)		(1,432)		(1,626)
Amortization of:
Transition obligation		1		-		2		2
Prior service (benefit) cost		(487)		28		(1,462)		83
Actuarial loss		28		310		86		930
Net periodic (benefit) cost	$	(131)	$	1,356	$	(393)	$	4,068

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Investment in ATC (Tables)

9 Months Ended

Sep. 30, 2014

Equity Method Investments and Joint Ventures [Abstract]

ATC's Summarized Financial Data

For the nine months endedSeptember 30,2014 and 2013, MGE Transco recorded the following:

		Nine Months Ended
		September 30,
(In thousands)		2014		2013
Equity in earnings from investment in ATC	$	7,306	$	7,045
Dividends received from ATC		5,762		5,498
Capital contributions to ATC		1,420		1,065

ATC's summarized financial data for the three and nine months endedSeptember 30,2014 and 2013, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Operating revenues	$	163,643	$	160,480	$	486,970	$	464,345
Operating expenses		(76,561)		(77,595)		(229,589)		(217,240)
Other income (expense), net		693		917		1,403		585
Interest expense, net		(22,204)		(21,136)		(66,442)		(63,232)
Earnings before members' income taxes	$	65,571	$	62,666	$	192,342	$	184,458

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Derivative and Hedging Instruments (Details-1) (USD $)										9 Months Ended	12 Months Ended									9 Months Ended		12 Months Ended
	Sep. 30, 2014	Sep. 30, 2014 Other Current Assets [Member]	Jun. 30, 2014 Other Current Assets [Member]	Dec. 31, 2013 Other Current Assets [Member]	Sep. 30, 2013 Other Current Assets [Member]	Jun. 30, 2013 Other Current Assets [Member]	Dec. 31, 2012 Other Current Assets [Member]	Sep. 30, 2014 Commodity Contracts And Financial Transimission Rights [Member]	Dec. 31, 2013 Commodity Contracts And Financial Transimission Rights [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] MWh Dth	Dec. 31, 2013 Commodity Derivative Contracts [Member] Dth MWh	Sep. 30, 2014 Commodity Derivative Contracts [Member] Other Current Assets [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Other Current Assets [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] Other Deferred Charges [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Other Deferred Charges [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Derivative Liability (Current) [Member]	Sep. 30, 2014 Commodity Derivative Contracts [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2013 Commodity Derivative Contracts [Member] Derivative Liability (Long-term) [Member]	Sep. 30, 2014 Energy Related Commodity Contract [Member] Cash Flow Hedging [Member]	Sep. 30, 2014 Financial Transmission Rights [Member] MW	Dec. 31, 2013 Financial Transmission Rights [Member] MW	Sep. 30, 2014 Financial Transmission Rights [Member] Other Current Assets [Member]	Dec. 31, 2013 Financial Transmission Rights [Member] Other Current Assets [Member]	Sep. 30, 2014 Financial Transmission Rights [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Financial Transmission Rights [Member] Derivative Liability (Current) [Member]	Sep. 30, 2014 Ten-year PPA [Member]	Dec. 31, 2013 Ten-year PPA [Member]	Sep. 30, 2014 Ten-year PPA [Member] Derivative Liability (Current) [Member]	Dec. 31, 2013 Ten-year PPA [Member] Derivative Liability (Current) [Member]	Sep. 30, 2014 Ten-year PPA [Member] Derivative Liability (Long-term) [Member]	Dec. 31, 2013 Ten-year PPA [Member] Derivative Liability (Long-term) [Member]
Derivatives Fair Value [Line Items]
Maximum term of derivative hedging contract																				4 years
Gross Notional Volume of Open Derivatives
Notional amount, energy measure (in MWh)										447,570	458,660
Notional amount, decatherm measure (in Dth)										6,555,000	3,750,000
Notional amount, power measure (in MW)																					3,104	1,984
Derivative, right to reclaim collateral (receivable)	$ 600,000
Derivative fair values [Abstract]
Derivative fair value, net		741,000	676,000	411,000	822,000	658,000	574,000	2,300,000	1,800,000																		(54,900,000)	(65,700,000)
Asset Derivatives, fair value, gross basis										1,555,000	1,523,000	1,507,000	1,356,000	48,000	167,000						1,237,000	363,000	1,237,000	363,000
Liability Derivatives, fair value, gross basis										$ 536,000	$ 99,000					$ 532,000	$ 51,000	$ 4,000	$ 48,000						$ 0	$ 0	$ 54,940,000	$ 65,680,000	$ 7,120,000	$ 7,750,000	$ 47,820,000	$ 57,930,000

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Commitments and Contingencies (Tables)

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Chattel Paper Agreement, Fiscal Year Maturity Schedule

Principal payments for the remainder of 2014 and the next four years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Chattel Paper	$	108	$	921	$	841	$	438	$	374

Purchase Contracts, Fiscal Year Maturity Schedule

As of September 30,2014, the future commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Coal(a)	$	11,950	$	18,439	$	10,765	$	5,073	$	2,710
Natural gas
Transportation & storage(b)		5,234		18,073		9,937		272		191
Supply(c)		16,951		16,070		-		-		-
Purchase power(d)		12,665		48,964		49,633		50,132		51,153
Other		16,102		-		-		-		-
	$	62,902	$	101,546	$	70,335	$	55,477	$	54,054

(a)Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurements for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, who are the operators of those facilities. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)MGE’s natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

(c)These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

(d)MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates.

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Derivative and Hedging Instruments (Tables)

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Gross Notional Volume of Open Derivatives

The gross notional volume of open derivatives is as follows:

	September 30, 2014	December 31, 2013
Commodity derivative contracts	447,570 MWh	458,660 MWh
Commodity derivative contracts	6,555,000 Dth	3,750,000 Dth
FTRs	3,104 MW	1,984 MW

Fair Value of Derivative Instruments on the Balance Sheet

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheet. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral. At September 30,2014, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $0.6 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2014
Commodity derivative contracts	Other current assets	$	1,507	Derivative liability (current)	$	532
Commodity derivative contracts	Other deferred charges		48	Derivative liability (long-term)		4
FTRs	Other current assets		1,237	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,120
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		47,820
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930

Offsetting Assets

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2014
Commodity derivative contracts	$	1,555	$	(525)	$	-	$	1,030
FTRs		1,237		-		-		1,237
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363

Offsetting Liabilities

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2014
Commodity derivative contracts	$	536	$	(525)	$	-	$	11
Ten-year PPA		54,940		-		-		54,940
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680

Derivative Gains and Losses in Balance Sheet

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at September 30,2014 and 2013, and the consolidated income statement for the three and nine months endedSeptember 30,2014 and 2013.

		2014				2013
(In thousands)		Current and long-term regulatory asset		Other current assets		Current and long-term regulatory asset		Other current assets
Three Months Ended September 30:
Balance at July 1,	$	48,853	$	676	$	66,649	$	658
Change in unrealized loss		5,329		-		2,330		-
Realized gain (loss) reclassified to a deferred
account		(314)		314		(275)		275
Realized gain (loss) reclassified to income
statement		(1,184)		(249)		(621)		(111)
Balance at September 30,	$	52,684	$	741	$	68,083	$	822
Nine Months Ended September 30:
Balance at January 1,	$	63,893	$	411	$	72,329	$	574
Change in unrealized gain		(18,090)		-		(1,330)		-
Realized gain (loss) reclassified to a deferred
account		1,120		(1,120)		(953)		953
Realized gain (loss) reclassified to income
statement		5,761		1,450		(1,963)		(705)
Balance at September 30,	$	52,684	$	741	$	68,083	$	822

Derivative Gains and Losses in Income Statement

		Realized losses (gains)
		2014				2013
(In thousands)		Fuel for electric generation/ purchased power		Cost of gas sold		Fuel for electric generation/ purchased power		Cost of gas sold
Three Months Ended September 30:
Commodity derivative contracts	$	480	$	(18)	$	(7)	$	-
FTRs		(97)		-		(387)		-
Ten-year PPA		1,068		-		1,126		-
Nine Months Ended September 30:
Commodity derivative contracts	$	(5,376)	$	(1,367)	$	(523)	$	608
FTRs		(929)		-		(896)		-
Ten-year PPA		461		-		3,479		-

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Madison Gas and Electric Company Consolidated Statements of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Items not affecting cash:
Depreciation and amortization	$ 30,191	$ 28,864
Deferred income taxes	24,376	32,706
Provision for doubtful receivables	1,001	1,551
Employee benefit plan expenses	(814)	9,908
Equity earnings in ATC	(7,306)	(7,045)
Other items	(843)	250
Changes in working capital items:
Decrease in current assets	13,318	15,053
Decrease in current liabilities	(7,515)	(5,496)
Dividend income from ATC	5,762	5,498
Cash contributions to pension and other postretirement plans	(2,449)	(33,919)
Debt make-whole premium	0	(6,757)
Other noncurrent items, net	118	7,159
Cash Provided by Operating Activities	120,972	108,600
Investing Activities:
Capital expenditures	(66,138)	(92,092)
Capital contributions to investments	(1,830)	(1,305)
Other	(1,265)	(780)
Cash Used for Investing Activities	(69,233)	(94,177)
Financing Activities:
Repayment of long-term debt	(3,069)	(42,000)
Issuance of long-term debt	0	85,000
Other	(130)	(765)
Cash (Used for) Provided by Financing Activities	(31,833)	14,550
Change in cash and cash equivalents	19,906	28,973
Cash and cash equivalents at beginning of period	68,813	46,357
Cash and Cash Equivalents at End of Period	88,719	75,330
Significant noncash investing activities:
Accrued capital expenditures	6,549	10,473
MGE [Member]
Operating Activities:
Net Income	65,255	60,856
Items not affecting cash:
Depreciation and amortization	30,156	28,864
Deferred income taxes	23,811	31,467
Provision for doubtful receivables	1,001	1,551
Employee benefit plan expenses	(814)	9,908
Equity earnings in ATC	(7,306)	(7,045)
Other items	(446)	652
Changes in working capital items:
Decrease in current assets	13,258	14,599
Decrease in current liabilities	(5,457)	(4,911)
Dividend income from ATC	5,762	5,498
Cash contributions to pension and other postretirement plans	(2,449)	(33,919)
Debt make-whole premium	0	(6,757)
Other noncurrent items, net	(24)	7,063
Cash Provided by Operating Activities	122,747	107,826
Investing Activities:
Capital expenditures	(66,138)	(92,092)
Capital contributions to investments	(1,420)	(1,065)
Other	(1,087)	(678)
Cash Used for Investing Activities	(68,645)	(93,835)
Financing Activities:
Cash dividends paid to parent by MGE	(26,500)	0
Distributions to parent from noncontrolling interest	(17,778)	(21,148)
Equity contribution received by noncontrolling interest	1,420	1,065
Repayment of long-term debt	(3,069)	(42,000)
Issuance of long-term debt	0	85,000
Other	0	(668)
Cash (Used for) Provided by Financing Activities	(45,927)	22,249
Change in cash and cash equivalents	8,175	36,240
Cash and cash equivalents at beginning of period	14,808	6,350
Cash and Cash Equivalents at End of Period	22,983	42,590
Significant noncash investing activities:
Accrued capital expenditures	$ 6,549	$ 10,473

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Fair Value of Financial Instruments (Tables)

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Estimated Fair Market Value of Financial Instruments

The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		September 30, 2014				December 31, 2013
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	88,719	$	88,719	$	68,813	$	68,813
Liabilities:
Long-term debt*		400,724		443,203		403,793		432,010
MGE
Assets:
Cash and cash equivalents	$	22,983	$	22,983	$	14,808	$	14,808
Liabilities:
Long-term debt*		400,724		443,203		403,793		432,010
*Includes long-term debt due within one year.

Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following table presents the balances of assets and liabilities measured at fair value on a recurring basis for MGE Energy and MGE.

		Fair Value as of September 30, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	2,267	$	417	$	-	$	1,850
Exchange-traded investments		886		886		-		-
Total Assets	$	3,153	$	1,303	$	-	$	1,850
Liabilities:
Derivatives, net	$	54,951	$	-	$	-	$	54,951
Deferred compensation		2,705		-		2,705		-
Total Liabilities	$	57,656	$	-	$	2,705	$	54,951
MGE
Assets:
Derivatives, net	$	2,267	$	417	$	-	$	1,850
Exchange-traded investments		341		341		-		-
Total Assets	$	2,608	$	758	$	-	$	1,850
Liabilities:
Derivatives, net	$	54,951	$	-	$	-	$	54,951
Deferred compensation		2,705		-		2,705		-
Total Liabilities	$	57,656	$	-	$	2,705	$	54,951

		Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(a)	$	1,787	$	735	$	-	$	1,052
Exchange-traded investments		792		792		-		-
Total Assets	$	2,579	$	1,527	$	-	$	1,052
Liabilities:
Derivatives, net	$	65,680	$	-	$	-	$	65,680
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	68,044	$	-	$	2,364	$	65,680
MGE
Assets:
Derivatives, net(a)	$	1,787	$	735	$	-	$	1,052
Exchange-traded investments		431		431		-		-
Total Assets	$	2,218	$	1,166	$	-	$	1,052
Liabilities:
Derivatives, net	$	65,680	$	-	$	-	$	65,680
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	68,044	$	-	$	2,364	$	65,680
(a) These amounts are shown gross and exclude $0.2 million of collateral that was
posted against derivative positions with counterparties as of December 31, 2013.

Significant Unobservable Inputs

The following table presents the significant unobservable inputs used in the pricing model.

	Model Input
Significant Unobservable Inputs	September 30, 2014	December 31, 2013
Basis adjustment:
On peak	97.5%	94.2%
Off peak	94.4%	92.6%
Counterparty fuel mix:
Internal generation	50% - 70%	50% - 70%
Purchased power	50% - 30%	50% - 30%

Changes in Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Beginning balance	$	(49,349)	$	(66,856)	$	(64,628)	$	(72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(3,752)		(1,472)		11,528		4,018
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,419)		(174)		5,837		(2,034)
Included in current assets		-		(38)		(89)		(94)
Purchases		6,371		6,052		19,900		17,709
Sales		-		-		(60)		(2)
Issuances		-		-		-		-
Settlements		(4,952)		(5,840)		(25,589)		(15,579)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(53,101)	$	(68,328)	$	(53,101)	$	(68,328)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(b)	$	-	$	-	$	-	$	-

(b)MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.

Gains and Losses Included in Income for Level 3 Assets and Liabilities Measured at Fair Value on a Recurring Basis

The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE(b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Purchased Power Expense	$	(1,411)	$	(174)	$	5,845	$	(2,034)
Cost of Gas Sold Expense		(8)		-		(8)		-
Total	$	(1,419)	$	(174)	$	5,837	$	(2,034)

(b)MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.

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Share Based Compensation (Details) (Performance Units [Member], USD $) In Millions, except Share data, unless otherwise specified	9 Months Ended			0 Months Ended	9 Months Ended	1 Months Ended	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Jan. 31, 2014	Feb. 21, 2014 Performance Unit Plan [Member]	Sep. 30, 2014 Performance Unit Plan [Member]	Jan. 31, 2014 Director Incentive Agreement [Member]	Sep. 30, 2014 Director Incentive Agreement [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awards granted during period (in units)				21,991		4,683
Award vesting period					5 years		3 years
Compensation expense	$ 0.9	$ 1.1
Cash payments distributed related to awards previously granted and now payable			1.2
Awards forfeited during period	0	0
Outstanding awards vested during period	$ 3.7

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Fair Value of Financial Instruments (Details-4) (USD $) In Thousands, unless otherwise specified	3 Months Ended				9 Months Ended
	Sep. 30, 2014		Sep. 30, 2013		Sep. 30, 2014		Sep. 30, 2013
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Beginning balance,	$ (49,349)		$ (66,856)		$ (64,628)		$ (72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)	(3,752)		(1,472)		11,528		4,018
Included in other comprehensive income	0		0		0		0
Included in earnings	(1,419)		(174)		5,837		(2,034)
Included in current assets	0		(38)		(89)		(94)
Purchases	6,371		6,052		19,900		17,709
Sales	0		0		(60)		(2)
Issuances	0		0		0		0
Settlements	(4,952)		(5,840)		(25,589)		(15,579)
Transfers in and/or out of level 3	0		0		0		0
Ending balance,	(53,101)		(68,328)		(53,101)		(68,328)
Total gains (losses) included in earnings attributed to the change in unrealized gains (losses) related to assets and liabilities	0	[1]	0	[1]	0	[1]	0	[1]
Purchased Power Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	(1,411)	[1]	(174)	[1]	5,845	[1]	(2,034)	[1]
Cost Of Gas Sold Expense [Member]
Realized and unrealized gains (losses):
Included in earnings	$ (8)	[1]	$ 0	[1]	$ (8)	[1]	$ 0	[1]

[1] MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.

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MGE Energy Inc Consolidated Statements of Income (Unaudited) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Operating Revenues:
Regulated electric revenues	$ 112,869	$ 119,836	$ 308,418	$ 310,176
Regulated gas revenues	21,404	18,864	163,335	121,373
Nonregulated revenues	862	1,399	2,392	4,075
Total Operating Revenues	135,135	140,099	474,145	435,624
Operating Expenses:
Fuel for electric generation	9,838	13,950	35,836	34,520
Purchased power	21,303	21,981	58,779	61,237
Cost of gas sold	11,039	8,819	107,679	70,259
Other operations and maintenance	37,587	41,134	118,267	124,670
Depreciation and amortization	10,376	9,710	30,191	28,864
Other general taxes	4,872	4,605	14,861	14,049
Total Operating Expenses	95,015	100,199	365,613	333,599
Operating Income	40,120	39,900	108,532	102,025
Other income, net	2,636	3,750	10,736	9,770
Interest expense, net	(5,141)	(4,605)	(14,550)	(13,937)
Income before income taxes	37,615	39,045	104,718	97,858
Income tax provision	(14,286)	(14,692)	(39,585)	(37,030)
Net Income (Loss)	$ 23,329	$ 24,353	$ 65,133	$ 60,828
Earnings Per Share of Common Stock (basic and diluted)	$ 0.67	$ 0.70	$ 1.88	$ 1.75
Dividends per share of common stock	$ 0.283	$ 0.272	$ 0.826	$ 0.799
Weighted Average Shares Outstanding (basic and diluted)	34,668	34,668	34,668	34,668

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Derivative and Hedging Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Offsetting Assets [Line Items]
Collateral posted against derivative positions	$ 0	$ (200)
Commodity Derivative Contracts [Member]
Offsetting Assets [Line Items]
Gross amounts	1,555	1,523
Gross amounts offset in balance sheet	(525)	(99)
Collateral posted against derivative positions	0	(175)
Net amount presented in balance sheet	1,030	1,249
Financial Transmission Rights [Member]
Offsetting Assets [Line Items]
Gross amounts	1,237	363
Gross amounts offset in balance sheet	0	0
Collateral posted against derivative positions	0	0
Net amount presented in balance sheet	$ 1,237	$ 363

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Consolidated Statements of Comprehensive Income (Unaudited) (Parantheticals) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Unrealized gain (loss) on available-for-sale securities, tax (benefit) expense	$ 63	$ 24	$ 38	$ 117
MGE [Member]
Unrealized gain (loss) on available-for-sale securities, tax (benefit) expense	$ 29	$ 33	$ (36)	$ 52

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Investment in ATC (Details-1) (USD $)	9 Months Ended					0 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014 MGE Transco [Member] ATC [Member]	Sep. 30, 2013 MGE Transco [Member] ATC [Member]	Dec. 31, 2013 MGE Transco [Member] ATC [Member]	Oct. 31, 2014 MGE Transco [Member] ATC [Member] Subsequent Event [Member]
Schedule Of Equity Method Investments [Line Items]
Equity earnings from investment	$ 7,306,000	$ 7,045,000	$ 7,306,000	$ 7,045,000
Dividend income from investment	5,762,000	5,498,000	5,762,000	5,498,000
Capital contributions to investment	1,830,000	1,305,000	1,420,000	1,065,000		400,000
Equity method investment			$ 67,500,000		$ 64,500,000

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Derivative and Hedging Instruments

9 Months Ended

Sep. 30, 2014

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Hedging Instruments

Derivative and Hedging Instruments - MGE Energy and MGE.

a. Purpose.

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices and gas revenues. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

b. Notional Amounts.

The gross notional volume of open derivatives is as follows:

	September 30, 2014	December 31, 2013
Commodity derivative contracts	447,570 MWh	458,660 MWh
Commodity derivative contracts	6,555,000 Dth	3,750,000 Dth
FTRs	3,104 MW	1,984 MW

c.Financial Statement Presentation.

MGE purchases and sells exchange-traded and over-the-counter options, swaps, and future contracts. These arrangements are primarily entered into to help stabilize the price risk associated with gas or power purchases. These transactions are employed by both MGE's gas and electric segments. Additionally, as a result of the firm transmission agreements that MGE holds on electricity transmission paths in the MISO market,MGE holdsFTRs. An FTR is a financial instrument that entitles the holder to a stream of revenues or charges based on the differences in hourly day-ahead energy prices between two points on the transmission grid. The fair values of these instruments are offset with a corresponding regulatory asset/liability depending on whether they are in a net loss/gain position. Depending on the nature of the instrument, the gain or loss associated with these transactions will be reflected as cost of gas sold, fuel for electric generation, or purchased power expense in the delivery month applicable to the instrument. At September 30,2014 and December 31,2013, the fair value of exchange traded derivatives and FTRs exceeded their cost basis by $2.3 million and $1.8 million, respectively.

MGE is a party to a ten-year purchased power agreement that provides MGE with firm capacity and energy during a base term from June 1, 2012, through May 31, 2022. The agreement also allows MGE an option to extend the contract after the base term. The agreement is accounted for as a derivative contract and is recognized at its fair value on the consolidated balance sheet. However, the derivative qualifies for regulatory deferral and is recognized with a corresponding regulatory asset or liability depending on whether the fair value is in a loss or gain position. The fair value of the contract at September 30,2014 and December 31, 2013, reflects a loss position of $54.9 million and $65.7 million, respectively. The actual fuel cost will be recognized in purchased power expense in the month of purchase and collected in rates.

The following table summarizes the fair value of the derivative instruments on the consolidated balance sheet. All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral. At September 30,2014, MGE Energy and MGE had the right to reclaim collateral (a receivable) of $0.6 million.

	Asset Derivatives			Liability Derivatives
(In thousands)	Balance Sheet Location		Fair Value	Balance Sheet Location		Fair Value
September 30, 2014
Commodity derivative contracts	Other current assets	$	1,507	Derivative liability (current)	$	532
Commodity derivative contracts	Other deferred charges		48	Derivative liability (long-term)		4
FTRs	Other current assets		1,237	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,120
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		47,820
December 31, 2013
Commodity derivative contracts	Other current assets	$	1,356	Derivative liability (current)	$	51
Commodity derivative contracts	Other deferred charges		167	Derivative liability (long-term)		48
FTRs	Other current assets		363	Derivative liability (current)		-
Ten-year PPA	N/A		N/A	Derivative liability (current)		7,750
Ten-year PPA	N/A		N/A	Derivative liability (long-term)		57,930

The following tables show the effect of netting arrangements for recognized derivative assets and liabilities that are subject to a master netting arrangement or similar arrangement on the balance sheet.

Offsetting of Derivative Assets
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2014
Commodity derivative contracts	$	1,555	$	(525)	$	-	$	1,030
FTRs		1,237		-		-		1,237
December 31, 2013
Commodity derivative contracts	$	1,523	$	(99)	$	(175)	$	1,249
FTRs		363		-		-		363

Offsetting of Derivative Liabilities
(In thousands)		Gross amounts		Gross amounts offset in balance sheet		Collateral posted against derivative positions		Net amount presented in balance sheet
September 30, 2014
Commodity derivative contracts	$	536	$	(525)	$	-	$	11
Ten-year PPA		54,940		-		-		54,940
December 31, 2013
Commodity derivative contracts	$	99	$	(99)	$	-	$	-
Ten-year PPA		65,680		-		-		65,680

The following tables summarize the unrealized and realized gains (losses) related to the derivative instruments on the consolidated balance sheet at September 30,2014 and 2013, and the consolidated income statement for the three and nine months endedSeptember 30,2014 and 2013.

		2014				2013
(In thousands)		Current and long-term regulatory asset		Other current assets		Current and long-term regulatory asset		Other current assets
Three Months Ended September 30:
Balance at July 1,	$	48,853	$	676	$	66,649	$	658
Change in unrealized loss		5,329		-		2,330		-
Realized gain (loss) reclassified to a deferred
account		(314)		314		(275)		275
Realized gain (loss) reclassified to income
statement		(1,184)		(249)		(621)		(111)
Balance at September 30,	$	52,684	$	741	$	68,083	$	822
Nine Months Ended September 30:
Balance at January 1,	$	63,893	$	411	$	72,329	$	574
Change in unrealized gain		(18,090)		-		(1,330)		-
Realized gain (loss) reclassified to a deferred
account		1,120		(1,120)		(953)		953
Realized gain (loss) reclassified to income
statement		5,761		1,450		(1,963)		(705)
Balance at September 30,	$	52,684	$	741	$	68,083	$	822

		Realized losses (gains)
		2014				2013
(In thousands)		Fuel for electric generation/ purchased power		Cost of gas sold		Fuel for electric generation/ purchased power		Cost of gas sold
Three Months Ended September 30:
Commodity derivative contracts	$	480	$	(18)	$	(7)	$	-
FTRs		(97)		-		(387)		-
Ten-year PPA		1,068		-		1,126		-
Nine Months Ended September 30:
Commodity derivative contracts	$	(5,376)	$	(1,367)	$	(523)	$	608
FTRs		(929)		-		(896)		-
Ten-year PPA		461		-		3,479		-

MGE's commodity derivative contracts, FTRs, and ten-year PPA are subject to regulatory deferral. These derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. Realized gains and losses are deferred on the consolidated balance sheet and are recognized in earnings in the delivery month applicable to the instrument. As a result of the above described treatment, there are no unrealized gains or losses that flow through earnings.

The ten-year PPA has a provision that may require MGE to post collateral if MGE's debt rating falls below investment grade (i.e., below BBB-). The amount of collateral that it may be required to post varies from $20.0 million to $40.0million, depending on MGE's nominated capacity amount. As of September 30,2014, no collateral has been posted. Certain counterparties extend MGE a credit limit. If MGE exceeds these limits, the counterparties may require collateral to be posted. As of September 30,2014, certain counterparties were in a net liability of less than $0.1 million. As of December 31, 2013, no counterparties were in a net liability position.

Nonperformance of counterparties to the non-exchange traded derivatives could expose MGE to credit loss. However, MGE enters into transactions only with companies that meet or exceed strict credit guidelines, and it monitors these counterparties on an ongoing basis to mitigate nonperformance risk in its portfolio. As of September 30,2014,no counterparties have defaulted.

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Investment in ATC (Details-2) (ATC [Member], USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
ATC [Member]
Schedule Of Equity Method Investments [Line Items]
Operating revenues	$ 163,643	$ 160,480	$ 486,970	$ 464,345
Operating expenses	(76,561)	(77,595)	(229,589)	(217,240)
Other income (expense), net	693	917	1,403	585
Interest expense, net	(22,204)	(21,136)	(66,442)	(63,232)
Earnings before members' income taxes	$ 65,571	$ 62,666	$ 192,342	$ 184,458

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Fair Value of Financial Instruments

9 Months Ended

Sep. 30, 2014

Fair Value Disclosures [Abstract]

Fair Value of Financial Instruments

Fair Value of Financial Instruments - MGE Energy and MGE.

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

a. Fair Value of Financial Assets and Liabilities Recorded at the Carrying Amount.

At September 30,2014 and December 31, 2013, the carrying amount of cash and cash equivalents approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30,2014 and December 31, 2013. Since long-term debt is not traded in an active market, it is classified as Level 2.The estimated fair market value of MGE Energy's and MGE's financial instruments are as follows:

		September 30, 2014				December 31, 2013
(In thousands)		Carrying Amount		Fair Value		Carrying Amount		Fair Value
MGE Energy
Assets:
Cash and cash equivalents	$	88,719	$	88,719	$	68,813	$	68,813
Liabilities:
Long-term debt*		400,724		443,203		403,793		432,010
MGE
Assets:
Cash and cash equivalents	$	22,983	$	22,983	$	14,808	$	14,808
Liabilities:
Long-term debt*		400,724		443,203		403,793		432,010
*Includes long-term debt due within one year.

b. Recurring Fair Value Measurements.

The following table presents the balances of assets and liabilities measured at fair value on a recurring basis for MGE Energy and MGE.

		Fair Value as of September 30, 2014
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net	$	2,267	$	417	$	-	$	1,850
Exchange-traded investments		886		886		-		-
Total Assets	$	3,153	$	1,303	$	-	$	1,850
Liabilities:
Derivatives, net	$	54,951	$	-	$	-	$	54,951
Deferred compensation		2,705		-		2,705		-
Total Liabilities	$	57,656	$	-	$	2,705	$	54,951
MGE
Assets:
Derivatives, net	$	2,267	$	417	$	-	$	1,850
Exchange-traded investments		341		341		-		-
Total Assets	$	2,608	$	758	$	-	$	1,850
Liabilities:
Derivatives, net	$	54,951	$	-	$	-	$	54,951
Deferred compensation		2,705		-		2,705		-
Total Liabilities	$	57,656	$	-	$	2,705	$	54,951

		Fair Value as of December 31, 2013
(In thousands)		Total		Level 1		Level 2		Level 3
MGE Energy
Assets:
Derivatives, net(a)	$	1,787	$	735	$	-	$	1,052
Exchange-traded investments		792		792		-		-
Total Assets	$	2,579	$	1,527	$	-	$	1,052
Liabilities:
Derivatives, net	$	65,680	$	-	$	-	$	65,680
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	68,044	$	-	$	2,364	$	65,680
MGE
Assets:
Derivatives, net(a)	$	1,787	$	735	$	-	$	1,052
Exchange-traded investments		431		431		-		-
Total Assets	$	2,218	$	1,166	$	-	$	1,052
Liabilities:
Derivatives, net	$	65,680	$	-	$	-	$	65,680
Deferred compensation		2,364		-		2,364		-
Total Liabilities	$	68,044	$	-	$	2,364	$	65,680
(a) These amounts are shown gross and exclude $0.2 million of collateral that was
posted against derivative positions with counterparties as of December 31, 2013.

No transfers were made in or out of Level 1 or Level 2 for the nine months endedSeptember 30,2014.

Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore considered unobservable and classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease and if the basis adjustment is increased, the fair value measurement will increase.

The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.

This model is prepared by members of MGE's Energy Accounting group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

The following table presents the significant unobservable inputs used in the pricing model.

	Model Input
Significant Unobservable Inputs	September 30, 2014	December 31, 2013
Basis adjustment:
On peak	97.5%	94.2%
Off peak	94.4%	92.6%
Counterparty fuel mix:
Internal generation	50% - 70%	50% - 70%
Purchased power	50% - 30%	50% - 30%

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

The following table summarizes the changes in Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Beginning balance	$	(49,349)	$	(66,856)	$	(64,628)	$	(72,346)
Realized and unrealized gains (losses):
Included in regulatory liabilities (assets)		(3,752)		(1,472)		11,528		4,018
Included in other comprehensive income		-		-		-		-
Included in earnings		(1,419)		(174)		5,837		(2,034)
Included in current assets		-		(38)		(89)		(94)
Purchases		6,371		6,052		19,900		17,709
Sales		-		-		(60)		(2)
Issuances		-		-		-		-
Settlements		(4,952)		(5,840)		(25,589)		(15,579)
Transfers in and/or out of Level 3		-		-		-		-
Balance as of September 30,	$	(53,101)	$	(68,328)	$	(53,101)	$	(68,328)
Total gains (losses) included in earnings attributed to
the change in unrealized gains (losses) related to
assets and liabilities held at September 30,(b)	$	-	$	-	$	-	$	-

The following table presents total realized and unrealized gains (losses) included in income for Level 3 assets and liabilities measured at fair value on a recurring basis for both MGE Energy and MGE(b).

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Purchased Power Expense	$	(1,411)	$	(174)	$	5,845	$	(2,034)
Cost of Gas Sold Expense		(8)		-		(8)		-
Total	$	(1,419)	$	(174)	$	5,837	$	(2,034)

(b)MGE's exchange-traded derivative contracts, over-the-counter party transactions, ten-year purchased power agreement, and FTRs are subject to regulatory deferral. These derivatives are therefore marked to fair value and are offset in the financial statements with a corresponding regulatory asset or liability.

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MGE Energy Inc Consolidated Statements of Cash Flows (Unaudited) (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Operating Activities:
Net Income	$ 65,133	$ 60,828
Items not affecting cash:
Depreciation and amortization	30,191	28,864
Deferred income taxes	24,376	32,706
Provision for doubtful receivables	1,001	1,551
Employee benefit plan expenses	(814)	9,908
Equity earnings in ATC	(7,306)	(7,045)
Other items	(843)	250
Changes in working capital items:
Decrease in current assets	13,318	15,053
Decrease in current liabilities	(7,515)	(5,496)
Dividend income from ATC	5,762	5,498
Cash contributions to pension and other postretirement plans	(2,449)	(33,919)
Debt make-whole premium	0	(6,757)
Other noncurrent items, net	118	7,159
Cash Provided by Operating Activities	120,972	108,600
Investing Activities:
Capital expenditures	(66,138)	(92,092)
Capital contributions to investments	(1,830)	(1,305)
Other	(1,265)	(780)
Cash Used for Investing Activities	(69,233)	(94,177)
Financing Activities:
Cash dividends paid on common stock	(28,634)	(27,685)
Repayment of long-term debt	(3,069)	(42,000)
Issuance of long-term debt	0	85,000
Other	(130)	(765)
Cash (Used for) Provided by Financing Activities	(31,833)	14,550
Change in cash and cash equivalents	19,906	28,973
Cash and cash equivalents at beginning of period	68,813	46,357
Cash and Cash Equivalents at End of Period	88,719	75,330
Significant noncash investing activities:
Accrued capital expenditures	$ 6,549	$ 10,473

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Madison Gas and Electric Company Consolidated Statements of Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Operating Revenues:
Regulated electric revenues	$ 112,869	$ 119,836	$ 308,418	$ 310,176
Regulated gas revenues	21,404	18,864	163,335	121,373
Nonregulated revenues	862	1,399	2,392	4,075
Total Operating Revenues	135,135	140,099	474,145	435,624
Operating Expenses:
Fuel for electric generation	9,838	13,950	35,836	34,520
Purchased power	21,303	21,981	58,779	61,237
Cost of gas sold	11,039	8,819	107,679	70,259
Other operations and maintenance	37,587	41,134	118,267	124,670
Depreciation and amortization	10,376	9,710	30,191	28,864
Other general taxes	4,872	4,605	14,861	14,049
Income tax provision	14,286	14,692	39,585	37,030
Total Operating Expenses	95,015	100,199	365,613	333,599
Operating Income	40,120	39,900	108,532	102,025
Other Income and Deductions:
Equity in earnings in ATC			7,306	7,045
Total Other Income and Deductions	2,636	3,750	10,736	9,770
Interest Expense:
Net Interest Expense	5,141	4,605	14,550	13,937
Net Income (Loss)	23,329	24,353	65,133	60,828
MGE [Member]
Operating Revenues:
Regulated electric revenues	112,875	119,836	308,435	310,176
Regulated gas revenues	21,410	18,864	163,351	121,373
Nonregulated revenues	862	1,399	2,392	4,075
Total Operating Revenues	135,147	140,099	474,178	435,624
Operating Expenses:
Fuel for electric generation	9,841	13,950	35,843	34,520
Purchased power	21,307	21,981	58,790	61,237
Cost of gas sold	11,045	8,819	107,695	70,259
Other operations and maintenance	37,309	40,990	117,593	124,133
Depreciation and amortization	10,364	9,710	30,156	28,864
Other general taxes	4,872	4,605	14,861	14,049
Income tax provision	13,338	13,798	36,180	34,237
Total Operating Expenses	108,076	113,853	401,118	367,299
Operating Income	27,071	26,246	73,060	68,325
Other Income and Deductions:
AFUDC - equity funds	255	852	3,306	2,178
Equity in earnings in ATC	2,423	2,340	7,306	7,045
Income tax provision	(984)	(880)	(3,390)	(2,802)
Other income, net	(111)	407	(351)	118
Total Other Income and Deductions	1,583	2,719	6,871	6,539
Income before interest expense	28,654	28,965	79,931	74,864
Interest Expense:
Interest on long-term debt	5,225	4,910	15,714	14,757
Other interest, net	44	5	52	(31)
AFUDC - borrowed funds	(84)	(281)	(1,090)	(718)
Net Interest Expense	5,185	4,634	14,676	14,008
Net Income Including Noncontrolling Interest	23,469	24,331	65,255	60,856
Less Net Income Attributable to Noncontrolling Interest, net of tax	(6,653)	(6,861)	(19,784)	(20,547)
Net Income (Loss)	$ 16,816	$ 17,470	$ 45,471	$ 40,309

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Columbia Environmental Project Construction

9 Months Ended

Sep. 30, 2014

Regulated Operations [Abstract]

Columbia Environmental Project Construction

Columbia Environmental Project Construction - MGE Energy and MGE.

MGE and two other utilities jointly own Columbia, a coal-fired generating facility. WPL is the plant operator and permit holder, and owns 46.2% of Columbia. WPSC owns a 31.8% interest, and MGE owns a 22% interest, in Columbia. In early 2011, the PSCW issued a Certificate and Order authorizing the construction of scrubbers and baghouses and associated equipment on Columbia Units 1 and 2 to reduce SO₂ and mercury emissions. The modifications to Unit 2 were placed into service in April 2014, and the modifications to Unit 1 were placed into service in July 2014. The scrubbers and baghouses are expected to support compliance obligations for current and anticipated air quality regulations, including CAIR, CSAPR, MATS, and the Wisconsin Mercury Rule. As of September 30,2014, $138.6 million of the capitalized project was transferred from Construction work in progress to Property, plant, and equipment on MGE's balance sheet related to Units 1 and 2 being placed into service. This total amount consisted of $128.8million of capital expenditures and $9.8million of AFUDC. MGE's share of various contractual commitments entered for the project as of September 30,2014 is $5.5 million. For the three months endedSeptember 30,2014 and 2013, MGE has recognized after tax $0.1 million and $0.8 million, respectively, in AFUDC equity related to this project. For the nine months endedSeptember 30,2014 and 2013, MGE has recognized after tax $3.0 million and $1.9 million, respectively, in AFUDC equity related to this project.

MGE expects that the costs pertaining to this project will be fully recoverable through rates. For 2014, the PSCW authorized MGE 100% AFUDC on this project during construction. For 2013, the PSCW authorized MGEa 50% current return (included in customer rates) and the remaining 50% as AFUDC.

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Document and Entity Information	9 Months Ended
	Sep. 30, 2014
Document And Entity Information [Line Items]
Entity Registrant Name	MGE Energy Inc
Entity Central Index Key	0001161728
Document Type	10-Q
Document Period End Date	Sep. 30, 2014
Amendment Flag	false
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	Q3
Current Fiscal Year End Date	--12-31
Entity Well known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Common Stock Shares Outstanding	34,668,370
MGE [Member]
Document And Entity Information [Line Items]
Entity Registrant Name	Madison Gas and Electric Company
Entity Central Index Key	0000061339
Entity Current Reporting Status	Yes
Entity Filer Category	Non-accelerated Filer
Entity Common Stock Shares Outstanding	17,347,894

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Taxes

9 Months Ended

Sep. 30, 2014

Income Tax Disclosure [Abstract]

Taxes

Taxes - MGE Energy and MGE.

MGE Energy's effective income tax rates for the three and nine months endedSeptember 30,2014, were 38.0% and 37.8%, respectively, compared to 37.6% and 37.8% for the same periods in 2013. MGE’s effective income tax rates for the three and nine months endedSeptember 30,2014, were 37.9% and 37.8%, respectively, compared to 37.6% and 37.8% for the same periods in 2013. The net increase in the three month effective tax rate is attributable to less AFUDC equity earned during the three month period in 2014 compared to 2013.

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MGE Energy Inc Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Comprehensive Income [Abstract]
Net Income	$ 23,329	$ 24,353	$ 65,133	$ 60,828
Other comprehensive income (loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	95	36	56	176
Comprehensive Income	$ 23,424	$ 24,389	$ 65,189	$ 61,004

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Madison Gas and Electric Company Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands, unless otherwise specified	Total USD ($)	MGE [Member] USD ($)	Common Stock [Member]	Common Stock [Member] MGE [Member] USD ($)	Additional Paid-In Capital [Member] MGE [Member] USD ($)	Retained Earnings [Member] MGE [Member] USD ($)	Accumulated Other Comprehensive (Loss)/Income [Member] USD ($)	Accumulated Other Comprehensive (Loss)/Income [Member] MGE [Member] USD ($)	Noncontrolling Interest [Member] MGE [Member] USD ($)
Beginning balance, value at Dec. 31, 2012		$ 550,766		$ 17,348	$ 192,417	$ 223,527		$ 4	$ 117,470
Beginning balance, shares at Dec. 31, 2012			34,668	17,348
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		60,856				40,309			20,547
Other comprehensive income (loss)	176	77					176	77
Equity contribution received by noncontrolling interest		1,065							1,065
Distributions to parent from noncontrolling interest		(21,148)							(21,148)
Ending balance, value at Sep. 30, 2013		591,616		17,348	192,417	263,836		81	117,934
Ending balance, shares at Sep. 30, 2013			34,668	17,348
Beginning balance, value at Jun. 30, 2013
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		24,331
Ending balance, value at Sep. 30, 2013		591,616		17,348	192,417
Ending balance, shares at Sep. 30, 2013			34,668	17,348
Beginning balance, value at Dec. 31, 2013		576,454		17,348	192,417	247,534		192	118,963
Beginning balance, shares at Dec. 31, 2013			34,668	17,348
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		65,255				45,471			19,784
Other comprehensive income (loss)	56	(54)					56	(54)
Cash dividends paid to parent by MGE		(26,500)				(26,500)
Equity contribution received by noncontrolling interest		1,420							1,420
Distributions to parent from noncontrolling interest		(17,778)							(17,778)
Ending balance, value at Sep. 30, 2014		598,797		17,348	192,417	266,505		138	122,389
Ending balance, shares at Sep. 30, 2014			34,668	17,348
Beginning balance, value at Jun. 30, 2014
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income		23,469
Ending balance, value at Sep. 30, 2014		$ 598,797		$ 17,348	$ 192,417
Ending balance, shares at Sep. 30, 2014			34,668	17,348

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MGE Energy Inc Consolidated Statements of Common Equity (Unaudited) (USD $) In Thousands, unless otherwise specified	Total	Common Stock [Member]	Additional Paid-In Capital [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income [Member]
Beginning balance, value at Dec. 31, 2012	$ 579,429	$ 34,668	$ 316,268	$ 228,399	$ 94
Beginning balance, shares at Dec. 31, 2012		34,668
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	60,828			60,828
Other comprehensive income (loss)	176				176
Common stock dividends declared	(27,685)			(27,685)
Ending balance, value at Sep. 30, 2013	612,748	34,668	316,268	261,542	270
Ending balance, shares at Sep. 30, 2013		34,668
Beginning balance, value at Dec. 31, 2013	617,510	34,668	316,268	266,197	377
Beginning balance, shares at Dec. 31, 2013		34,668
Increase (Decrease) In Stockholders' Equity [Roll Forward]
Net Income	65,133			65,133
Other comprehensive income (loss)	56				56
Common stock dividends declared	(28,634)			(28,634)
Cash in lieu of fractional shares related to stock split	(80)			(80)
Ending balance, value at Sep. 30, 2014	$ 653,985	$ 34,668	$ 316,268	$ 302,616	$ 433
Ending balance, shares at Sep. 30, 2014		34,668

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Rate Matters

9 Months Ended

Sep. 30, 2014

Regulated Operations [Abstract]

Rate Matters

Rate Matters - MGE Energy and MGE.

a. Rate Proceedings.

On April 17, 2014, MGE filed an application with the PSCW requesting a 2.8% increase to electric rates and a 2.3% decrease to gas rates for 2015. MGE has requested escrow accounting treatment for transmission related costs starting in 2015. This treatment will allow MGE to reflect any differential between costs reflected in rates and actual costs incurred in its next rate case filing. The proposed electric rate increases cover costs associated with the construction of emission-reduction equipment at Columbia and improvements and reliability of the state's electric transmission system.

During the rate case proceeding, certain updates have been made to reflect changing conditions from the initial filing. Those updates include increased costs for fuel and purchased power costs primarily related to coal delivery costs, lower transmission costs due to favorable FERC decisions on cost allocations for system reliability payments, and increased costs to reflect current market conditions for pension and post-retirement benefit costs. Incorporating the revisions would adjust the electric rate increase from 2.8% to 4.3% and adjust the gas rate decrease from 2.3% to 1.4%. A PSCW decision is expected by the end of 2014.

On July 26, 2013, the PSCW authorized MGE to freeze electric and natural gas rates at 2013 levels for 2014. The order includes authorizing 100% AFUDC on the Columbia scrubber construction project and deferral of increased costs related to ATC and MISO Schedule 26 fees. As part of the rate freeze plan authorized by the PSCW, effective January 1, 2014, approximately $6.2 million associated with a 2012 fuel rule surplus credit will not be required to be refunded to customers and will be amortized in 2014. The fuel credit will accrue interest at MGE's weighted cost of capital. The authorized return on equity remained unchanged at 10.3%.

On December 14, 2012, the PSCW authorized MGE to increase 2013 rates for retail electric customers by 3.8% or $14.9 million and to increase gas rates by 1.0% or $1.6 million. The change in retail electric rates was driven by costs for new environmental equipment at Columbia, final construction costs for the Elm Road Units, transmission reliability enhancements, and purchased power costs. The authorized return on common stock equity remained unchanged at 10.3%.

b. Fuel Rules.

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

As of September 30,2014, MGE did not defer any 2014 electric fuel-related savings/costs that are outside the range authorized by the PSCW. As part of the rate freeze plan authorized by the PSCW for 2014, $4.7 million of the approximately $6.2 million associated with the 2012 fuel rule surplus credit was amortized against purchased power expense during the nine months endedSeptember 30,2014. The 2013 fuel rule surplus credit of $6.7 million was returned to customers in October 2014.

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Pension and Other Postretirement Plans

9 Months Ended

Sep. 30, 2014

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans

Pension and Other Postretirement Plans - MGE Energy and MGE.

MGE maintains qualified and nonqualified pension plans, health care, and life insurance benefits. Additionally, MGE has defined contribution 401(k) benefit plans.

The following table presents the components of MGE Energy's and MGE's net periodic benefit costs recognized for the three and nine months endedSeptember 30,2014 and 2013. A portion of the net periodic benefit cost is capitalized within the consolidated balance sheets.

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Pension Benefits
Components of net periodic (benefit) cost:
Service cost	$	1,536	$	1,924	$	4,609	$	5,764
Interest cost		3,367		3,178		10,102		9,521
Expected return on assets		(5,467)		(4,764)		(16,402)		(14,273)
Amortization of:
Prior service cost		51		79		152		237
Actuarial loss		180		2,011		539		6,023
Net periodic (benefit) cost	$	(333)	$	2,428	$	(1,000)	$	7,272
Postretirement Benefits
Components of net periodic (benefit) cost:
Service cost	$	241	$	594	$	722	$	1,781
Interest cost		564		966		1,691		2,898
Expected return on assets		(478)		(542)		(1,432)		(1,626)
Amortization of:
Transition obligation		1		-		2		2
Prior service (benefit) cost		(487)		28		(1,462)		83
Actuarial loss		28		310		86		930
Net periodic (benefit) cost	$	(131)	$	1,356	$	(393)	$	4,068

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Equity and Financing Arrangements

9 Months Ended

Sep. 30, 2014

Equity and Financing Arrangements Disclosure [Abstract]

Equity and Financing Arrangements

Equity and Financing Arrangements.

a. Common Stock - MGE Energy.

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC. For both the nine months endedSeptember 30,2014 and 2013, MGE Energy did not issue any new shares of common stock under the Stock Plan.

b. Dilutive Shares Calculation - MGE Energy.

MGE Energy does not hold any dilutive securities.

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Consolidated Statements of Common Equity (Unaudited) (Parentheticals) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Consolidated Statements of Common Equity
Dividends per share of common stock	$ 0.283	$ 0.272	$ 0.826	$ 0.799

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Basis of Presentation

9 Months Ended

Sep. 30, 2014

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Basis of Presentation - MGE Energy and MGE.

This report is a combined report of MGE Energy and MGE. References in this report to "MGE Energy" are to MGE Energy, Inc. and its subsidiaries. References in this report to "MGE" are to Madison Gas and Electric Company.

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus. See Footnote 2 of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2013 Annual Report on Form 10-K.

The accompanying consolidated financial statements as of September 30,2014, and for the three and nine months ended, are unaudited, but include all adjustments that MGE Energy and MGE management consider necessary for a fair statement of their respective financial statements. All adjustments are of a normal, recurring nature except as otherwise disclosed. The year-end consolidated balance sheet information was derived from the audited balance sheet appearing in MGE Energy's and MGE's 2013 Annual Report on Form 10-K, but does not include all disclosures required by accounting principles generally accepted in the United States of America. These notes should be read in conjunction with the financial statements and the notes on pages 57 through 100 of the 2013 Annual Report on Form 10-K.

On December 20, 2013, MGE Energy's Board of Directors declared a three-for-two stock split of MGE Energy's common stock in the form of a stock dividend. The additional shares were distributed February 7, 2014 to all shareholders of record as of January 24, 2014. All shares and per share data provided in this report give effect to this stock split.

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Investment in ATC

9 Months Ended

Sep. 30, 2014

Equity Method Investments and Joint Ventures [Abstract]

Investment in ATC

Investment in ATC - MGE Energy and MGE.

ATC owns and operates electric transmission facilities primarily in Wisconsin. MGE received an interest in ATC when it, like other Wisconsin electric utilities, contributed its electric transmission facilities to ATC as required by Wisconsin law. That interest is presently held by MGE Transco, which is jointly owned by MGE Energy and MGE.

MGE Transco has accounted for its investment in ATC under the equity method of accounting.For the nine months endedSeptember 30,2014 and 2013, MGE Transco recorded the following:

		Nine Months Ended
		September 30,
(In thousands)		2014		2013
Equity in earnings from investment in ATC	$	7,306	$	7,045
Dividends received from ATC		5,762		5,498
Capital contributions to ATC		1,420		1,065

On October 31, 2014, MGE Transco made an additional $0.4million capital contribution to ATC.

MGE Transco's investment in ATC as of September 30,2014 and December 31, 2013 was $67.5 million and $64.5 million, respectively.

At September 30,2014, MGE is the majority owner, and MGE Energy, the holding company, is the minority owner of MGE Transco. MGE Energy's proportionate share of the equity and net income of MGE Transco is classified within the MGE financial statements as noncontrolling interest.

ATC's summarized financial data for the three and nine months endedSeptember 30,2014 and 2013, is as follows:

		Three Months Ended				Nine Months Ended
		September 30,				September 30,
(In thousands)		2014		2013		2014		2013
Operating revenues	$	163,643	$	160,480	$	486,970	$	464,345
Operating expenses		(76,561)		(77,595)		(229,589)		(217,240)
Other income (expense), net		693		917		1,403		585
Interest expense, net		(22,204)		(21,136)		(66,442)		(63,232)
Earnings before members' income taxes	$	65,571	$	62,666	$	192,342	$	184,458

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Equity and Financing Arrangements (Details) (USD $)	9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013
Common Stock [Abstract]
Common stock issued during period	0	0
Dilutive Shares Calculation [Abstract]
Dilutive securities	$ 0

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Fair Value of Financial Instruments (Details-2) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Liabilities:
Derivative asset, collateral offset	$ 0	$ 200
Recurring [Member]
Assets:
Derivative assets, net	2,267	1,787	[1]
Total Assets	3,153	2,579
Liabilities:
Derivative liabilities, net	54,951	65,680
Deferred compensation	2,705	2,364
Total liabilities	57,656	68,044
Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	886	792
Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net	417	735	[1]
Total Assets	1,303	1,527
Liabilities:
Derivative liabilities, net	0	0
Deferred compensation	0	0
Total liabilities	0	0
Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	886	792
Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net	0	0	[1]
Total Assets	0	0
Liabilities:
Derivative liabilities, net	0	0
Deferred compensation	2,705	2,364
Total liabilities	2,705	2,364
Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net	1,850	1,052	[1]
Total Assets	1,850	1,052
Liabilities:
Derivative liabilities, net	54,951	65,680
Deferred compensation	0	0
Total liabilities	54,951	65,680
Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member]
Liabilities:
Derivative asset, collateral offset	0	200
MGE [Member] | Recurring [Member]
Assets:
Derivative assets, net	2,267	1,787	[1]
Total Assets	2,608	2,218
Liabilities:
Derivative liabilities, net	54,951	65,680
Deferred compensation	2,705	2,364
Total liabilities	57,656	68,044
MGE [Member] | Recurring [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	341	431
MGE [Member] | Recurring [Member] | Level 1 [Member]
Assets:
Derivative assets, net	417	735	[1]
Total Assets	758	1,166
Liabilities:
Derivative liabilities, net	0	0
Deferred compensation	0	0
Total liabilities	0	0
MGE [Member] | Recurring [Member] | Level 1 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	341	431
MGE [Member] | Recurring [Member] | Level 2 [Member]
Assets:
Derivative assets, net	0	0	[1]
Total Assets	0	0
Liabilities:
Derivative liabilities, net	0	0
Deferred compensation	2,705	2,364
Total liabilities	2,705	2,364
MGE [Member] | Recurring [Member] | Level 2 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	0	0
MGE [Member] | Recurring [Member] | Level 3 [Member]
Assets:
Derivative assets, net	1,850	1,052	[1]
Total Assets	1,850	1,052
Liabilities:
Derivative liabilities, net	54,951	65,680
Deferred compensation	0	0
Total liabilities	54,951	65,680
MGE [Member] | Recurring [Member] | Level 3 [Member] | Exchange Traded [Member]
Assets:
Available-for-sale securities	$ 0	$ 0

[1] These amounts are shown gross and exclude $0.2 million of collateral that was posted against derivative positions with counterparties as of December 31, 2013.

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Commitments and Contingencies

9 Months Ended

Sep. 30, 2014

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies - MGE Energy and MGE.

a. Environmental.

MGE Energy and MGE are subject to frequently changing local, state, and federal regulations concerning air quality, water quality, land use, threatened and endangered species, hazardous materials handling, and solid waste disposal. These regulations affect the manner in which they conduct their operations, the costs of those operations, as well as capital and operating expenditures. Regulatory initiatives, proposed rules, and court challenges to adopted rules, have the potential to have a material effect on our capital expenditures and operating costs. These initiatives, proposed rules, and court challenges include:

The President's announced plan and directive to the EPA to regulate carbon pollution, or greenhouse gas (GHG) emissions, from new and existing electric power generation units, and the EPA's related proposed GHG New Source Performance Standards (NSPS) (see below for additional information on the NSPS rule).

Rules to regulate NO_x and SO₂ emissions, including the EPA's Cross State Air Pollution Rule (CSAPR) (see below for recent developments with CSAPR). An environmental group has sought federal appellate court review of the EPA’s Clean Air Visibility Rule (CAVR) to address regional haze. Both the pending challenges to CSAPR and the appellate court review of CAVR make the nature of compliance requirements uncertain.

Rules to regulate mercury and similar emissions, including Wisconsin's adopted Mercury Rule and the EPA's adopted Mercury and Air Toxics Standards.

The EPA's cooling water intake rules. The EPA issued a final rule for existing facilities in May 2014. The final rule is discussed below.

The EPA's proposed water effluent limitations guidelines and standards for steam electric power plants, which focus on the reduction of metals and other pollutants in wastewater from new and existing power plants from coal-burning plants such as Columbia and the Elm Road Units.

The EPA's ongoing review of several National Ambient Air Quality Standards (NAAQS), including the potential lowering of the ozone NAAQS and its proposed requirements for air agencies to characterize sulfur dioxide air quality for purposes of implementing the 1-hour SO₂ NAAQS. This approach focuses on large sources of SO₂ emissions and proposes area designations to be made in two rounds (2017 and 2020). The proposed rule gives states broad discretion in its implementation. The final rule is expected late in 2014. MGE will be reviewing the rule for potential impacts on its operations.

The matters in the bullet points above are discussed further in Footnote 18.d. of Notes to Consolidated Financial Statements under Item 8, Financial Statements and Supplementary Data, of MGE Energy's and MGE's 2013 Annual Report on Form 10-K. In addition to the developments noted above, the following discussion is an update to the current status of environmental matters set forth in that Footnote.

EPA's Final 316(b) Rule Governing Water Intake Systems at Electric Generating Facilities

In August 2014, the EPA published its Phase II and III Rules pursuant to Section 316(b) of the Clean Water Act, which governs cooling water intake structures located at large existing power plant and industrial facilities. The 316(b) Rule requires these facilities to implement methods for reducing fish impingement by their water intakes using one of seven options, including closed cycle cooling (CCC) systems.

Our WCCF facility already employs a CCC system as defined under the Rule. The Columbia plant may need to address multiple intake structures. Our Blount plant has conducted studies regarding options for compliance with this rule. The exact requirements at Blount and Columbia, however, will not be known until those sites' permits are modified to account for this rule. Nonetheless, MGE expects that the 316(b) Rule will not have material effects on its existing plants.

EPA's Cross-State Air Pollution Rule (CSAPR) Upheld by the Supreme Court

On April 29, 2014, the US Supreme Court issued a decision reversing the D.C. Circuit Court's decision that had vacated CSAPR and remanding the matter back to the D.C. Circuit for further proceedings. At that time CSPAR remained subject to an order of the D.C. Circuit that stayed its implementation. On October 23, 2014, the D.C. Circuit lifted its stay of CSAPR and set a briefing schedule to resolve issues remaining in the lawsuit. The court also set the briefing schedule for ongoing litigation with oral arguments scheduled for March 2015. The State of Wisconsin has filed a motion with the D.C. Circuit Court reiterating its contention that Wisconsin be removed from CSAPR and may be a part of the court’s briefing and oral argument schedule. With several issues undecided and court proceedings extending into 2015, there is remaining uncertainty as to whether MGE's facilities will be required to meet the CSAPR mandates and, if so, the deadline for achieving compliance. The Clean Air Interstate Rule (CAIR) remains in effect for the time being. See MGE Energy's and MGE's 2013 Annual Report on Form 10K for additional information on the legal proceedings associated with these environmental matters.

With CSAPR now reinstated, it will require (once implemented) that qualifying power plants meet SO₂ and NO_x allocations or purchase them on the market. MGE has been monitoring our overall compliance options, particularly at our Columbia power plant as we awaited installation and testing of SO₂ controls. With the 2014 installation of SO₂ pollution controls at Columbia, we will likely meet or exceed the allocations for Columbia based on the CSAPR allocations in the current rule (see Footnote 4 for information regarding the Columbia environmental construction project and below in this Footnote for information regarding our consent decree). MGE expects that the costs pertaining to meeting CSAPR and the consent decree requirements will be fully recoverable through rates. We will continue to monitor and evaluate the D.C. Circuit Court remand proceedings and the implementation of the rule by the EPA and WDNR.

EPA's Greenhouse Gas Reduction Guidelines under the Clean Air Act 111(d) Rule

On June 2, 2014, the EPA released proposed guidelines for states to use in developing plans to control GHG emissions from existing fossil fuel fired electric generating units (EGUs). The proposed rule was published in the Federal Register on June 17, 2014.

The EPA's proposal seeks to reduce GHG emissions from EGUs by a national average of 30% by 2030 as measured from a 2005 baseline. Each state is given its own emission reduction targets to meet this goal. These targets are expressed as a "rate-based" emission average to be achieved by the combined fleet of EGUs within the state. States would be expected to make "meaningful progress" towards these reductions by 2020 and to meet their respective targets by 2030.

The EPA's proposal establishes guidelines for states and encourages the use of four "building blocks" for achieving these reductions. These "building blocks" are: (1) increasing the efficiency of EGUs; (2) re-dispatching of gas-fired generation at the expense of coal; (3) expanding the use of low and no carbon power sources, such as wind, nuclear and solar; and (4) improving demand side energy efficiency to reduce electric use.

The EPA is taking comments on the proposed rule through December 1, 2014. The rule is expected to be finalized by June 2015. States will then have up to two years to prepare compliance plans. This rule could have significant impacts on EGUs. MGE is reviewing the proposal at this time.

Coal Combustion Residual Rule

The EPA's proposed Coal Combustion Residual (CCR) Rule is anticipated to be finalized in December 2014. The final CCR Rule will regulate disposal and management of ash and other coal combustion byproducts as a waste under the EPA's solid waste rules.

Columbia

Based upon current available information, compliance with various environmental requirements and initiatives is expected to result in significant additional operating and capital expenditures at Columbia as noted below.

Columbia Environmental Project

See Footnote 4 for information regarding the Columbia environmental construction project.

Columbia Clean Air Act Litigation

In December 2009, the EPA sent a notice of violation (NOV) to MGE and the other co-owners of Columbia. The NOV alleged that WPL, as owner-operator, and the other co-owners failed to comply with appropriate pre-construction review and permitting requirements and, as a result, violated the PSD program requirements, the Title V operating permit requirements of the CAA and the Wisconsin State Implementation Plan (SIP). In April 2013, the EPA filed a lawsuit against the co-owners of Columbia asserting similar allegations. In September 2010 and April 2013, Sierra Club filed lawsuits against WPL alleging violations of the CAA at Columbia and other WPL-operated Wisconsin facilities.

In April 2013, WPL, as owner-operator, along with the other owners of Columbia, entered into a consent decree with the EPA and the Sierra Club to resolve these claims, while admitting no liability. In June 2013, the consent decree was approved and entered by the Court. The consent decree requires installation of the following emission controls at Columbia: SO₂ scrubbers and baghouses at Columbia Units 1 and 2 by December 31, 2014, which have now been installed, and an SCR system at Columbia Unit 2 by December 31, 2018. In addition, the consent decree establishes emission rate limits for SO₂, NO_x, and particulate matter for Columbia Units 1 and 2. The consent decree also includes annual plant-wide emission caps for SO₂and NO_x for Columbia. MGE also paid approximately $0.2 million as its share of a civil penalty and will complete approximately $0.6 million in environmental mitigation projects. MGE intends to seek recovery in rates of the costs associated with its compliance with the terms of the final consent decree and currently expects to recover any material compliance costs.

b. Chattel Paper Agreement and Other Guarantees.

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2015. At September 30,2014, MGE had sold a $4.1 million interest in these receivables. MGE retains the servicing responsibility for these receivables. As of September 30,2014, the servicing asset recognized by MGE is $0.2 million.

MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.

MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at September 30,2014, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan.Principal payments for the remainder of 2014 and the next four years on the loans are:

(In thousands)		2014		2015		2016		2017		2018
Chattel Paper	$	108	$	921	$	841	$	438	$	374

c. Legal Matters.

MGE is involved in various legal matters that are being defended and handled in the normal course of business. MGE maintains accruals for such costs that are probable of being incurred and subject to reasonable estimation. The accrued amount for these matters is not material to the financial statements.

d. Purchase Contracts.

MGE Energy and MGE have entered into various commodity supply, transportation, and storage contracts to meet their obligations to deliver electricity and natural gas to customers. As of September 30,2014, the future commitments related to these purchase contracts were as follows:

(In thousands)		2014		2015		2016		2017		2018
Coal(a)	$	11,950	$	18,439	$	10,765	$	5,073	$	2,710
Natural gas
Transportation & storage(b)		5,234		18,073		9,937		272		191
Supply(c)		16,951		16,070		-		-		-
Purchase power(d)		12,665		48,964		49,633		50,132		51,153
Other		16,102		-		-		-		-
	$	62,902	$	101,546	$	70,335	$	55,477	$	54,054

(a)Total coal commitments for the Columbia and Elm Road Units, including transportation. Fuel procurements for MGE's jointly owned Columbia and Elm Road Units are handled by WPL and WEPCO, respectively, who are the operators of those facilities. If any minimum purchase obligations must be paid under these contracts, management believes these obligations would be considered costs of service and recoverable in rates.

(b)MGE’s natural gas transportation and storage contracts require fixed monthly payments for firm supply pipeline transportation and storage capacity. The pricing components of the fixed monthly payments for the transportation and storage contracts are established by FERC but may be subject to change.

(c)These commitments include market-based pricing. Management expects to recover these costs in future customer rates.

(d)MGE has several purchase power agreements to help meet future electric supply requirements. Management expects to recover these costs in future customer rates.

e.Elm Road - MGE Energy and MGE.

The warranty periods for both of the Elm Road Units have expired. During 2013, WEPCO and Bechtel (the construction contractor for the Elm Road Units) were working through theoutstanding warranty claims. The warranty claim for the costs incurred to repair steam turbine corrosion damage identified on both units was resolved through a binding arbitration in June 2013. Final acceptance of the Elm Road Units occurred in June 2013 after all requirements stated in the contract with Bechtel were satisfied. In April 2014, an additional warranty claim was resolved that did not have a material impact on our financial statements. The parties continue to work through one potential remaining warranty claim.

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Segment Information

9 Months Ended

Sep. 30, 2014

Segment Reporting [Abstract]

Segment Information

Segment Information - MGE Energy and MGE.

MGE Energy operates in the following business segments: electric utility, gas utility, nonregulated energy, transmission investment, and all other. See MGE Energy's and MGE's 2013 Annual Report on Form 10-K for additional discussion of each of these segments.

The following tables show segment information for MGE Energy's operations for the indicated periods:

(In thousands)MGE Energy		Electric		Gas		Non- Regulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2014
Operating revenues	$	112,869	$	21,404	$	862	$	-	$	-	$	-	$	135,135
Interdepartmental revenues		156		1,614		10,674		-		-		(12,444)		-
Total operating revenues		113,025		23,018		11,536		-		-		(12,444)		135,135
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		(12)		-		(10,376)
Other operating expenses		(74,573)		(22,199)		(35)		-		(276)		12,444		(84,639)
Operating income (loss)		31,521		(756)		9,643		-		(288)		-		40,120
Other income, net		136		8		-		2,423		69		-		2,636
Interest (expense) income, net		(2,832)		(808)		(1,545)		-		44		-		(5,141)
Income (loss) before taxes		28,825		(1,556)		8,098		2,423		(175)		-		37,615
Income tax (provision) benefit		(10,758)		651		(3,251)		(963)		35		-		(14,286)
Net income (loss)	$	18,067	$	(905)	$	4,847	$	1,460	$	(140)	$	-	$	23,329
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		-		(9,710)
Other operating expenses		(82,414)		(21,485)		(33)		(1)		(145)		13,589		(90,489)
Operating income (loss)		31,169		(1,361)		10,238		(1)		(145)		-		39,900
Other income, net		1,166		92		-		2,340		152		-		3,750
Interest (expense) income, net		(2,309)		(729)		(1,596)		-		29		-		(4,605)
Income (loss) before taxes		30,026		(1,998)		8,642		2,339		36		-		39,045
Income tax (provision) benefit		(11,021)		751		(3,469)		(939)		(14)		-		(14,692)
Net income (loss)	$	19,005	$	(1,247)	$	5,173	$	1,400	$	22	$	-	$	24,353
Nine Months Ended September 30, 2014
Operating revenues	$	308,418	$	163,335	$	2,392	$	-	$	-	$	-	$	474,145
Interdepartmental revenues		401		7,130		32,017		-		-		(39,548)		-
Total operating revenues		308,819		170,465		34,409		-		-		(39,548)		474,145
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		(35)		-		(30,191)
Other operating expenses		(229,286)		(144,907)		(105)		-		(672)		39,548		(335,422)
Operating income (loss)		59,624		20,858		28,757		-		(707)		-		108,532
Other (deductions) income, net		2,999		(44)		-		7,306		475		-		10,736
Interest (expense) income, net		(7,571)		(2,429)		(4,676)		-		126		-		(14,550)
Income (loss) before taxes		55,052		18,385		24,081		7,306		(106)		-		104,718
Income tax provision		(19,602)		(7,378)		(9,665)		(2,924)		(16)		-		(39,585)
Net income (loss)	$	35,450	$	11,007	$	14,416	$	4,382	$	(122)	$	-	$	65,133
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		-		(28,864)
Other operating expenses		(235,390)		(111,494)		(96)		(1)		(537)		42,783		(304,735)
Operating income (loss)		56,057		15,971		30,535		(1)		(537)		-		102,025
Other income, net		2,226		69		-		7,045		430		-		9,770
Interest (expense) income, net		(7,028)		(2,166)		(4,814)		-		71		-		(13,937)
Income (loss) before taxes		51,255		13,874		25,721		7,044		(36)		-		97,858
Income tax (provision) benefit		(18,148)		(5,844)		(10,209)		(2,837)		8		-		(37,030)
Net income (loss)	$	33,107	$	8,030	$	15,512	$	4,207	$	(28)	$	-	$	60,828

The following tables show segment information for MGE's operations for the indicated periods:

(In thousands)MGE		Electric		Gas		Non- Regulated Energy		Transmission Investment		Consolidation/ Elimination Entries		Consolidated Total
Three Months Ended September 30, 2014
Operating revenues	$	112,875	$	21,410	$	862	$	-	$	-	$	135,147
Interdepartmental revenues		150		1,608		10,674		-		(12,432)		-
Total operating revenues		113,025		23,018		11,536		-		(12,432)		135,147
Depreciation and amortization		(6,931)		(1,575)		(1,858)		-		-		(10,364)
Other operating expenses*		(85,314)		(21,544)		(3,286)		-		12,432		(97,712)
Operating income (loss)*		20,780		(101)		6,392		-		-		27,071
Other income, net*		119		4		-		1,460		-		1,583
Interest expense, net		(2,832)		(808)		(1,545)		-		-		(5,185)
Net income (loss)		18,067		(905)		4,847		1,460		-		23,469
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,653)		(6,653)
Net income (loss) attributable to MGE	$	18,067	$	(905)	$	4,847	$	1,460	$	(6,653)	$	16,816
Three Months Ended September 30, 2013
Operating revenues	$	119,836	$	18,864	$	1,399	$	-	$	-	$	140,099
Interdepartmental revenues		172		2,757		10,660		-		(13,589)		-
Total operating revenues		120,008		21,621		12,059		-		(13,589)		140,099
Depreciation and amortization		(6,425)		(1,497)		(1,788)		-		-		(9,710)
Other operating expenses*		(93,481)		(20,748)		(3,502)		(1)		13,589		(104,143)
Operating income (loss)*		20,102		(624)		6,769		(1)		-		26,246
Other income, net*		1,212		106		-		1,401		-		2,719
Interest expense, net		(2,309)		(729)		(1,596)		-		-		(4,634)
Net income (loss)		19,005		(1,247)		5,173		1,400		-		24,331
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(6,861)		(6,861)
Net income (loss) attributable to MGE	$	19,005	$	(1,247)	$	5,173	$	1,400	$	(6,861)	$	17,470
Nine Months Ended September 30, 2014
Operating revenues	$	308,435	$	163,351	$	2,392	$	-	$	-	$	474,178
Interdepartmental revenues		384		7,114		32,017		-		(39,515)		-
Total operating revenues		308,819		170,465		34,409		-		(39,515)		474,178
Depreciation and amortization		(19,909)		(4,700)		(5,547)		-		-		(30,156)
Other operating expenses*		(248,525)		(152,182)		(9,770)		-		39,515		(370,962)
Operating income*		40,385		13,583		19,092		-		-		73,060
Other (deductions) income, net*		2,636		(147)		-		4,382		-		6,871
Interest expense, net		(7,571)		(2,429)		(4,676)		-		-		(14,676)
Net income		35,450		11,007		14,416		4,382		-		65,255
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(19,784)		(19,784)
Net income attributable to MGE	$	35,450	$	11,007	$	14,416	$	4,382	$	(19,784)	$	45,471
Nine Months Ended September 30, 2013
Operating revenues	$	310,176	$	121,373	$	4,075	$	-	$	-	$	435,624
Interdepartmental revenues		410		10,449		31,924		-		(42,783)		-
Total operating revenues		310,586		131,822		35,999		-		(42,783)		435,624
Depreciation and amortization		(19,139)		(4,357)		(5,368)		-		-		(28,864)
Other operating expenses*		(253,566)		(117,346)		(10,305)		(1)		42,783		(338,435)
Operating income (loss)*		37,881		10,119		20,326		(1)		-		68,325
Other income, net*		2,254		77		-		4,208		-		6,539
Interest expense, net		(7,028)		(2,166)		(4,814)		-		-		(14,008)
Net income		33,107		8,030		15,512		4,207		-		60,856
Less: Net income attributable to
noncontrolling interest, net of tax		-		-		-		-		(20,547)		(20,547)
Net income attributable to MGE	$	33,107	$	8,030	$	15,512	$	4,207	$	(20,547)	$	40,309
*Amounts are shown net of the related tax expense, consistent with the presentation on the consolidated MGE Income Statement.

The following table shows segment information for MGE Energy's and MGE's assets and capital expenditures:
		Utility						Consolidated
(In thousands)MGE Energy		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		All Others		Consolidation/ Elimination Entries		Total
Assets:
September 30, 2014	$	914,839	$	263,688	$	30,962	$	307,599	$	67,476	$	443,898	$	(408,566)	$	1,619,896
December 31, 2013		899,257		265,694		19,853		288,116		64,504		431,436		(389,800)		1,579,060
Capital Expenditures:
Nine Months Ended September 30, 2014	$	50,033	$	14,599	$	-	$	1,506	$	-	$	-	$	-	$	66,138
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		-		119,047

		Utility						Consolidated
(In thousands)MGE		Electric		Gas		Assets not Allocated		Nonregulated Energy		Transmission Investment		Elimination Entries		Total
Assets:
September 30, 2014	$	917,503	$	262,237	$	30,778	$	286,600	$	67,476	$	(5,892)	$	1,558,702
December 31, 2013		899,257		265,694		19,853		288,066		64,504		(6,731)		1,530,643
Capital Expenditures:
Nine Months Ended September 30, 2014	$	50,033	$	14,599	$	-	$	1,506	$	-	$	-	$	66,138
Year ended Dec. 31, 2013		100,146		15,554		-		3,347		-		-		119,047

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Rate Matters (Details) (PSCW [Member], USD $) In Millions, unless otherwise specified	9 Months Ended		12 Months Ended			9 Months Ended	12 Months Ended	9 Months Ended	12 Months Ended			9 Months Ended	12 Months Ended
	Sep. 30, 2014 Legal Entity Type of Counterparty [Domain]	Sep. 30, 2014 MGE [Member]	Dec. 31, 2013 MGE [Member]	Sep. 30, 2014 MGE [Member] Fuel Rules Surplus Credit, 2012 [Member]	Sep. 30, 2014 MGE [Member] Fuel Rules Surplus Credit, 2013 [Member]	Sep. 30, 2014 Columbia Environmental Project [Member] MGE [Member]	Dec. 31, 2013 Columbia Environmental Project [Member] MGE [Member]	Sep. 30, 2014 Electric [Member] MGE [Member]	Dec. 31, 2013 Electric [Member] MGE [Member]	Dec. 31, 2015 Electric [Member] Proposed Future Rate Matters [Member] MGE [Member]	Dec. 31, 2015 Electric [Member] Proposed Future Rate Matters - Revised From Initial Filing [Member] MGE [Member]	Sep. 30, 2014 Gas [Member] MGE [Member]	Dec. 31, 2013 Gas [Member] MGE [Member]	Dec. 31, 2015 Gas [Member] Proposed Future Rate Matters [Member] MGE [Member]	Dec. 31, 2015 Gas [Member] Proposed Future Rate Matters - Revised From Initial Filing [Member] MGE [Member]
Rate Proceedings [Abstract]
Proposed rate increase (decrease), percentage										2.80%	4.30%			(2.30%)	(1.40%)
Authorized rate increase (decrease), percentage								0.00%	3.80%			0.00%	1.00%
Authorized rate increase (decrease), amount								$ 0	$ 14.9			$ 0	$ 1.6
Authorized AFUDC Rate						100.00%	50.00%
Return of electric fuel credit, total				6.2	6.7
Authorized return on equity, percentage		10.30%	10.30%
Fuel Rules [Abstract]
Fuel rules, bandwidth	2.00%
Fuel rules, electric fuel deferred costs upper threshold	102.00%
Fuel rules, electric fuel deferred costs lower threshold	98.00%
Return of electric fuel credit, current period				$ 4.7

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Commitments and Contingencies (Details-1) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2014 Columbia Units [Member]	Jun. 17, 2014 EPA [Member]
Public Utilities, General Disclosures [Line Items]
National average reduction of greenhouse gas emissions by the year 2030, percentage		30.00%
Columbia Commitments [Abstract]
Accrual for future environmental mitigation projects	$ 0.6
Envrionmental civil penalty expense	$ 0.2

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Madison Gas and Electric Company Consolidated Statements of Comprehensive Income (Unaudited) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	$ 95	$ 36	$ 56	$ 176
Comprehensive Income	23,424	24,389	65,189	61,004
MGE [Member]
Net Income	23,469	24,331	65,255	60,856
Other comprehensive income/(loss), net of tax:
Unrealized gain (loss) on available-for-sale securities, net of tax	43	49	(54)	77
Total comprehensive income including noncontrolling interest	23,512	24,380	65,201	60,933
Less: Comprehensive income attributable to Noncontrolling Interest, net of tax	(6,653)	(6,861)	(19,784)	(20,547)
Comprehensive Income	$ 16,859	$ 17,519	$ 45,417	$ 40,386

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Consolidated Balance Sheets (Unaudited) (Parentheticals) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2014	Dec. 31, 2013
Receivables, Net
Reserve for uncollectible accounts receivable	$ 4,056	$ 4,219
Reserve for uncollectible other accounts receivable	448	750
MGE [Member]
Receivables, Net
Reserve for uncollectible accounts receivable	4,056	4,219
Reserve for uncollectible other accounts receivable	$ 448	$ 750

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Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2014

Accounting Policies [Abstract]

Variable Interest Entities

MGE Power Elm Road and MGE Power West Campus own electric generating assets and lease those assets to MGE. Both entities are variable interest entities under applicable authoritative guidance. MGE is considered the primary beneficiary of these entities as a result of contractual agreements. As a result, MGE has consolidated MGE Power Elm Road and MGE Power West Campus.

Common Stock

MGE Energy sells shares of its common stock through its Stock Plan. Those shares may be newly issued shares or shares that MGE Energy has purchased in the open market for resale to participants in the Stock Plan. All sales under the stock plan are covered by a shelf registration statement that MGE Energy filed with the SEC.

Investments - ATC

MGE Transco has accounted for its investment in ATC under the equity method of accounting.

Share-based Compensation

Under MGE Energy'sPerformance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

In addition to units granted in 2009 through 2013, on February 21, 2014, 21,991 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule and reflect the three-for-two stock split declared December 20, 2013. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30,2014, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

Chattel Paper Agreement

MGE makes available to qualifying customers a financing program for the purchase and installation of energy-related equipment that will provide more efficient use of utility service at the customer's property. MGE is party to a chattel paper purchase agreement with a financial institution under which it can sell or finance an undivided interest with recourse, in up to $10.0 million of the financing program receivables, until July 31, 2015.

MGE retains the servicing responsibility for these receivables.

MGE accounts for servicing rights under the amortization method. Initial determination of the servicing asset fair value is based on the present value of the estimated future cash flows. The discount rate is based on the PSCW authorized weighted cost of capital.

MGE would be required to perform under its guarantee if a customer defaulted on its loan. The energy-related equipment installed at the customer sites is used to secure the customer loans. The loan balances outstanding at September 30,2014, approximate the fair value of the energy-related equipment acting as collateral. The length of the MGE guarantee to the financial institution varies from one to ten years depending on the term of the underlying customer loan.

Derivative Hedging

As part of its regular operations, MGE enters into contracts, including options, swaps, futures, forwards, and other contractual commitments, to manage its exposure to commodity prices and gas revenues. To the extent that these contracts are derivatives, MGE assesses whether or not the normal purchases or normal sales exclusion applies. For contracts to which this exclusion cannot be applied, MGE Energy and MGE recognize such derivatives in the consolidated balance sheets at fair value. The majority of MGE's derivative activities are conducted in accordance with its electric and gas risk management program, which is approved by the PSCW and limits the volume MGE can hedge with specific risk management strategies. The maximum length of time over which cash flows related to energy commodities can be hedged is four years. If the derivative qualifies for regulatory deferral, the derivatives are marked to fair value and are offset with a corresponding regulatory asset or liability. The deferred gain or loss is recognized in earnings in the delivery month applicable to the instrument. Gains and losses related to hedges qualifying for regulatory treatment are recoverable in gas rates through the PGA or in electric rates as a component of the fuel rules mechanism.

Derivative Netting

All derivative instruments in this table are presented on a gross basis and are calculated prior to the netting of instruments with the same counterparty under a master netting agreement as well as the netting of collateral. For financial statement purposes, MGE Energy and MGE have netted instruments with the same counterparty under a master netting agreement as well as the netting of collateral.

Wisconsin Fuel Rules

Fuel rules require the PSCW and Wisconsin utilities to defer electric fuel-related costs that fall outside a symmetrical cost tolerance band around the amount approved for a utility in its most recent base rate proceedings. Any over/under recovery of the actual costs is determined on an annual basis and will be adjusted in future billings to electric retail customers. The fuel rules bandwidth is currently set at plus or minus 2%. Under fuel rules, MGE would defer costs, less any excess revenues, if its actual electric fuel costs exceeded 102% of the electric fuel costs allowed in its latest rate order. Excess revenues are defined as revenues in the year in question that provide MGE with a greater return on common equity than authorized by the PSCW in MGE's latest rate order. Conversely, MGE is required to defer the benefit of lower costs if actual electric fuel costs were less than 98% of the electric fuel costs allowed in that order.

Recurring Fair Value Measurements

Fair value is defined as the price that would be received to sell an asset or would be paid to transfer a liability (an exit price) in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants at the measurement date. The standard clarifies that fair value should be based on the assumptions market participants would use when pricing the asset or liability including assumptions about risk. The standard also establishes a three level fair value hierarchy based upon the observability of the assumptions used and requires the use of observable market data when available. The levels are:

Level 1 - Pricing inputs are quoted prices within active markets for identical assets or liabilities.

Level 2 - Pricing inputs are quoted prices within active markets for similar assets or liabilities; quoted prices for identical or similar instruments in markets that are not active; and model-derived valuations that are correlated with or otherwise verifiable by observable market data.

Level 3 - Pricing inputs are unobservable and reflect management's best estimate of what market participants would use in pricing the asset or liability.

At September 30,2014 and December 31, 2013, the carrying amount of cash and cash equivalents approximates fair market value due to the short maturity of those investments and obligations. The estimated fair market value of MGE Energy's and MGE's long-term debt is based on quoted market prices for similar financial instruments at September 30,2014 and December 31, 2013. Since long-term debt is not traded in an active market, it is classified as Level 2.

Investments include exchange-traded investment securities valued using quoted prices on active exchanges and are therefore classified as Level 1.

Derivatives include exchange-traded derivative contracts, over-the-counter transactions, a ten-year purchased power agreement, and FTRs. Most exchange-traded derivative contracts are valued based on unadjusted quoted prices in active markets and are therefore classified as Level 1. A small number of exchange-traded derivative contracts are valued using quoted market pricing in markets with insufficient volumes and are therefore classified as Level 3. Transactions done with an over-the-counter party are on inactive markets and are therefore considered unobservable and classified as Level 3. These transactions are valued based on quoted prices from markets with similar exchange traded transactions. FTRs are priced based upon monthly auction results for identical or similar instruments in a closed market with limited data available and are therefore classified as Level 3.

The ten-year purchased power agreement (see Footnote 9) was valued using an internally-developed pricing model and therefore is classified as Level 3. The model projects future market energy prices and compares those prices to the projected power costs to be incurred under the contract. Inputs to the model require significant management judgment and estimation. Future energy prices are based on a forward power pricing curve using exchange-traded contracts in the electric futures market, where such exchange-traded contracts exist, and upon calculations based on forward gas prices, where such exchange-traded contracts do not exist. A basis adjustment is applied to the market energy price to reflect the price differential between the market price delivery point and the counterparty delivery point. The historical relationship between the delivery points is reviewed and a discount (below 100%) or premium (above 100%) is derived. This comparison is done for both peak times when demand is high and off peak times when demand is low. If the basis adjustment is lowered, the fair value measurement will decrease and if the basis adjustment is increased, the fair value measurement will increase.

The projected power costs anticipated to be incurred under the purchased power agreement are determined using many factors, including historical generating costs, future prices, and expected fuel mix of the counterparty. An increase in the projected fuel costs would result in a decrease in the fair value measurement of the purchased power agreement. A significant input that MGE estimates is the counterparty's fuel mix in determining the projected power cost. MGE also considers the assumptions that market participants would use in valuing the asset or liability. This consideration includes assumptions about market risk such as liquidity, volatility, and contract duration. The fair value model uses a discount rate that incorporates discounting, credit, and model risks.

This model is prepared by members of MGE's Energy Accounting group. It is reviewed on a quarterly basis by management in Energy Supply and Finance to review the assumptions, inputs, and fair value measurements.

The following table presents the significant unobservable inputs used in the pricing model.

	Model Input
Significant Unobservable Inputs	September 30, 2014	December 31, 2013
Basis adjustment:
On peak	97.5%	94.2%
Off peak	94.4%	92.6%
Counterparty fuel mix:
Internal generation	50% - 70%	50% - 70%
Purchased power	50% - 30%	50% - 30%

The deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. These amounts are included within other deferred liabilities in the consolidated balance sheets of MGE Energy and MGE. The notional investments earn interest based upon the semiannual rate of U.S. Treasury Bills having a 26 week maturity increased by 1% compounded monthly with a minimum annual rate of 7%, compounded monthly. The notional investments are based upon observable market data, however, since the deferred compensation obligations themselves are not exchanged in an active market, they are classified as Level 2.

New Accounting Pronouncements Disclosure

New Accounting Pronouncements - MGE Energy and MGE.

a.Obligations Resulting from Joint and Several Liability Arrangements for Which the Total Amount of the Obligation is Fixed at the Reporting Date.

In February 2013, the FASB issued authoritative guidance within the Codification's Balance Sheet topic that provides guidance on the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. This authoritative guidance became effective January 1, 2014. The authoritative guidance did not have a financial or disclosure impact.

b. Presentation of an Unrecognized Tax Benefit.

In July 2013, the FASB issued authoritative guidance within the Codification's Income Statement topic that provides guidance on the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The authoritative guidance was issued to eliminate diversity in practice by providing guidance on the presentation of unrecognized tax benefits. This authoritative guidance became effective January 1, 2014. The authoritative guidance will not have a financial statement or disclosure impact, unlessMGE Energy or its subsidiaries are in a net operating loss position. MGE Energy or its subsidiaries are currently not in a net operating loss position.

c.Revenue from Contracts with Customers.

In May 2014, the FASB issued authoritative guidance within the Codification's Revenue Recognition topic that provides guidance on the recognition, measurement, and disclosure of revenue from contracts with customers. This authoritative guidance will become effective January 1, 2017. MGE Energy and MGE are currently assessing the impact this pronouncement will have on their financial statements.

d.Transfers and Servicing Assets.

In June 2014, the FASB issued authoritative guidance within the Codification's Transfers and Servicing topic that provides guidance on the accounting and disclosures for repurchase-to-maturity transactions, securities lending transactions, and repurchase financings. This authoritative guidance will become effective January 1, 2015. The authoritative guidance will change the accounting for the Chattel Paper program. Prior to adoption of the standard, Chattel Paper was treated as an off-balance sheet arrangement. Upon adoption, assets and liabilities will increase approximately $4.0 million and additional disclosures will be required. The cumulative impact of this guidance on our financial statements is not expected to be material.

XML

Taxes (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2014	Sep. 30, 2013	Sep. 30, 2014	Sep. 30, 2013
Income Tax Disclosure [Line Items]
Effective income tax rate	38.00%	37.60%	37.80%	37.80%
MGE [Member]
Income Tax Disclosure [Line Items]
Effective income tax rate	37.90%	37.60%	37.80%	37.80%

XML

Share-Based Compensation

9 Months Ended

Sep. 30, 2014

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Share-Based Compensation

Share-Based Compensation - MGE Energy and MGE.

Under MGE Energy'sPerformance Unit Plan, eligible employees may receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend equivalent payments thereon, at the end of the set performance period.

In addition to units granted in 2009 through 2013, on February 21, 2014, 21,991 units were granted based on the MGE Energy closing stock price as of that date. These units are subject to a five-year graded vesting schedule and reflect the three-for-two stock split declared December 20, 2013. On the grant date, MGE Energy and MGE measure the cost of the employee services received in exchange for a performance unit award based on the current market value of MGE Energy common stock. The fair value of the awards has been subsequently re-measured at September 30,2014, as required by applicable accounting standards. Changes in fair value have been recognized as compensation cost. Since this amount is re-measured quarterly throughout the vesting period, the compensation cost is subject to variability.

For nonretirement eligible employees, stock based compensation costs are accrued and recognized using the graded vesting method. Compensation cost for retirement eligible employees or employees that will become retirement eligible during the vesting schedule are recognized on an abridged horizon.

In December 2013, a Director Incentive Plan was approved for the non-employee members of the Board of Directors. This plan is similar to MGE Energy's Performance Unit Plan for eligible employees described above. Under the plan, a non-employee director can receive performance units that entitle the holder to receive a cash payment equal to the value of a designated number of shares of MGE Energy's common stock, plus dividend payments, at the end of the set performance period. The units are subject to a three-year graded vesting schedule. In January 2014, unit awards of 4,683 (post-split) were granted to the non-employee Directors. For accounting purposes, the awards will be measured similarly to the employee unit awards.

During the nine months endedSeptember 30,2014 and 2013, MGE recorded $0.9 million and $1.1 million, respectively, in compensation expense as a result of the plans. In January 2014, cash payments of $1.2 million were distributed relating to awards that were granted in 2009. No forfeitures occurred during the nine months endedSeptember 30,2014 or 2013. At September 30,2014, $3.7 million of outstanding awards are vested.